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192-054
ti OF Tit, h*.\11/7,.c. THE STATE Alaska Oil and Gas oConservation Commission fALASIc:A S f i 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rh Main: 907.279.1433 OF ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov October 24, 2016 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verifications �NEDY,�'': Z�1 1=` PBU 12-06A PTD 1920540 Dear Ms. Cocklan-Vendl: On October 16,2016 an Alaska Oil and Gas Conservation Commission(AOGCC)Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-06A. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-06A. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree bled to zero within 3 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-06A demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, K7 James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDC WellIntegrityCoordinator(&,bp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Rp i ,u/j& DATE: Sunday, October 16, 2016 P. I. Supervisor / FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector PBU 12-06A BP Exploration Inc. PTD 1920540 Sunday, October 16, 2016: I witnessed the No Flow verification for BP Exploration's well PBU 12-06A in the Prudhoe Bay Unit. I met Ryan Moore (BP well integrity engineer) on location for the test. Mr. Moore explained that the Gas to liquid ratio had increased calling for another No-Flow test. The details are contained in the table below. Note that the time column is in chronological order. There was no flow observed from the well in the open top tank. The following table shows test details: Time Pressures1 Flow Rate (psi) Gas - scf/hr Liquid - gal/hr Remarks 0:00 0/57/87 - 0 0 Start recorder 09:18 A.M. - 0:05 0/57/87 S/I S/I Shut Tubing to tank block valve. 3:05 7/56/84 S/I S/I Open tubing to tank block valve 3:06 3/56/84 -- -- Venting tubing to tank - 3:07 0/56/84 -- -- Venting tubing to tank - 3:08 0/56/84 -- -- No flow observed 3:09 0/56/84 -- -- No flow observed 3:10 0/56/84 __ __ No flow observed, S/I block valve 3:06 0/56/84 - -- -- No buildup observed. 3:07 0/56/84 -- -- No buildup observed. 3:08 0/56/84 -- -- No buildup observed. 3:09 0/56/84 -- -- No buildup observed. 3:10 0/56/84 Conclude test. 1 Pressures are T/IA/OA Summary: I witnessed the No Flow test for BPX well PBU 12-06A in the Prudhoe Bay Field. It meets the criteria set forth for this type test. - Attachments: None - SCANNED APP 0 r 201 2016-1016_No-Flow_PBU_12-06A_lg.docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, April 13, 2015 3:41 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OIL; AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL;AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;AK, D&C WL&Completions Coordinator; Regg,James B (DOA) Subject: OPERABLE: Producer 12-06A (PTD#1920540) Passing No Flow Test - Permission to Flow Well Without Sub Surface Safety Valve Attachments: image001.png; BPXA No-Flow Verification, PBU 12-06A.pdf All, Producer 12-06A(PTD#1920540) passed an AOGCC witnessed no flow test (NFT)on April 06, 2015. The no flow test confirms that the well is not capable of unassisted flow of hydrocarbons to surface. The AOGCC has approved BP to produce the well without a sub-surface safety valve(SSSV). The well has been reclassified as Operable and may be placed on production without a SSSV. A NFT must be performed again if the well is perforated, cleaned out, stimulated in any way, or shows any sign of being capable of flowing hydrocarbons to surface unassisted. BP Base Management shall monitor for changes in flow characteristics to ensure the well remains incapable of flowing hydrocarbons to surface. The approval letter from the AOGCC is attached. Please call with any questions. Thank you, Kevin Parks SCANNE /AN,: 2 3 2015 (Alternate Wutney Pettus) BP Alaska-Well Integrity Coordinator G VV Global Wells �/�( Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C !V- - =• Coordinator Sent: Saturday, April 11, 2015 . To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; , c• S1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wire! - o=- . ions Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, •- secialists; AK, OPS Prod 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggj 414c4l,5- DATE: 4/6/15 P. I. Supervisor - / FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector PBU 12-06A BPX PTD 1920540 -- 4/6/15: 4/6/15: I arrived at PBU 12-06A at 9:30 am to witness a no flow test. I met with BPXA representative Ryan Holt and we went over BPXA's no flow procedure. They had shut the gas lift off and opened the well up to atmospheric pressure to bleed down at 3:30 am. I inspected the rig up and then had the well shut in for a 3 hour build up time. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 945 0/382/60 • 0 - 0 Well shut in to test 1045 22/376/60 0 0 Well shut in for build up 1145 39/375/60 - 0 0 Well shut in for build up 1245 49/374/60 • 0 0 Well opened to bleed down 1249 0/374/60 0 0 Well was dead 1 Pressures are T/IA/OA Summary: At 12:45 (after a 3 hour build up time) the tubing pressure was 49 psi. The tubing was opened up and within 3.5 min the pressure was at 0 psi and there was no si low. PBU 12-06A appears to meet the criteria for a no flow determination Attachments: none scow 3, 2015-0406_No-Flow_PBU12-06A_bn.docx Page 1 of 1 • Iiii/114' Alaska Oil and Gas cv ,.. ss THE STATE m� --s -'� o Conservation Commission rdijiii fALAS� ::ice_ __ ux_ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 of a*�„F GOVERNOR BILL WALKER g Main: 907.279 1433 ALAS14. Fax: 907.276.7542 www.aogcc.alaska gov April 13, 2015 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verification woo PBU 12-06A PTD 1920540 Dear Ms. Cocklan-Vendl: On April 6, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-06A. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-06A. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. 1 Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank, the well demonstrated the discharge of well pressure within four minutes. Liquid and gas flow rates were unmeasurable. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-06A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, y James B. Regg Supervisor, Petroleum Inspections cc: P. Brooks AOGCC Inspectors AKOPSFF WellOpsCompRep@bp.com AKDC WellIntegrityCoordinator@bp.com Ryan Daniel, BPXA gyro/data Gyrodata Incorporated 1111 23000 Northwest Lake Dr. Houston,TX 77095 (281)213-6300 Fax:(281)213-6301 r_e_jo 2_0 2OI � SCANNED MAR 0 920h1 i 12x2_9. 051 J II%V L__ I I`D#RT BP Exploration Drill Site:Wellhead 12; Well 12-06A: 4 1/2" North Slope, AK AK111 GCM207 2 November, 2011 Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data Gyrodata Incorporated • 23000 Northwest Lake Dr. Houston,TX 77095 (281)213-6300 Fax:(281)213-6301 January 3, 2012 State of Alaska -AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site:Wellhead 12; Well 12-06A: 4 1/2" North Slope, AK Enclosed,please find two (2) copies, and one(1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob Shoup North American Regional Manager RS:fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation • • a) U 0 N s. a) N a) •0 0 O O N cC 0 U O m U al _O O 0 O E .) O 3 a) a) o z H cd 3 U do0L OU �C cC .b C >, f24 c N U N -d ct U W , cYd oO N N 0 U° U 0 I-. N - N Np4 H C z HO � U NO P. o N Q : > U 2 �U z �. QO � -a- .- x o P- , 9 a7 inti N 6 0 = O .9- 04 a) :.- >, U O .� VD +-. O t 4 -a-) H 3 on E 0 -o ~ o Z U � z on H I) F N •n 0 o _ o a) U o. z "7/- > = N N O N p. o '-a- N o .'� O td Y OU .. U c) < z -0 N N '0 a) on y.; N O cUC G U O F" C 4-. o •'t.. O cC U 0 co z Q > U O> > p W N >, cG Cl) U cry cr < 0 • • w wwww wwwww wwwww ww CD O VD D\ 00 [- ^ 00 7r '0 ,---) N O oo M M V M N CN ^ 00 v) O 00 O O VD ^ M LT.) O O O O O O M 1--: N N M pvl VD 0000 O O - N2 O z 00 GO U0 GO Cl) Cl) GO U0 U0 & zZZZ Z Z --O D1 Cl co o0 Q\ DD O O VD O kr! 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O III11111 1 1 1 1 1111 1111 111111111 11111111 11 CL > U 0 olD l!1 0 o0 0 0 0 0 0 0 0mvJ d 0 (41) 9NIH12iON Survey QC - RGS-ClApecification Sheet • ;f;. "` SURVEY QUALITY CONTROL - SPECIFICATION DATA PRE-JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 65 265.91 -504.81 -0.00012622 -28.86 64 265.91 -493.91 -0.00012350 -31.07 63 222.60 -402.93 -0.00010075 -19.86 62 222.60 -423.52 -0.00010589 -23.52 61 41.84 -389.13 -0.00009730 -0.96 60 41.84 -397.99 -0.00009951 -2.22 59 356.52 -21.30 -0.00000532 -18.15 58 356.52 -28.50 -0.00000712 -17.02 57 12.52 67620.02 0.01943581 231.42 56 326.17 -55.34 -0.00001381 -25.49 55 326.17 -52.45 -0.00001309 -26.52 54 298.39 -260.95 -0.00006518 -29.69 53 298.39 -250.67 -0.00006262 -29.67 52 269.60 -463.43 -0.00011587 -25.56 51 269.60 -474.59 -0.00011866 -24.89 50 238.50 -498.04 -0.00012456 -14.44 49 238.50 -492.77 -0.00012324 -15.16 48 209.58 -295.59 -0.00007388 -2.03 47 209.58 -288.81 -0.00007218 -2.54 46 180.25 -46.62 -0.00001164 10.52 45 180.25 -58.18 -0.00001453 11.70 44 153.39 -19.24 -0.00000480 18.07 43 153.39 -22.04 -0.00000550 17.86 42 122.73 -205.13 -0.00005124 18.75 41 122.73 -206.79 -0.00005165 19.87 40 90.40 -436.23 -0.00010908 15.27 39 90.39 -443.94 -0.00011100 14.10 38 59.85 -482.82 -0.00012076 6.69 37 59.85 -482.04 -0.00012056 7.96 36 34.47 -344.85 -0.00008620 -3.48 35 34.47 -346.23 -0.00008655 -3.83 34 2.08 -93.07 -0.00002324 -24.41 33 2.08 -90.21 -0.00002253 -24.28 32 302.30 -192.71 -0.00004814 -22.66 31 302.31 -180.37 -0.00004505 -23.11 30 269.86 -403.68 -0.00010094 -24.92 29 269.86 -373.80 -0.00009348 -22.87 28 226.72 -426.63 -0.00010668 -9.94 27 226.72 -434.69 -0.00010870 -10.00 26 44.35 -407.16 -0.00010181 2.55 25 44.35 -400.20 -0.00010007 1.52 24 2.31 -119.08 -0.00002973 -16.41 23 2.31 -113.61 -0.00002837 -19.74 22 329.68 -52.81 -0.00001318 -24.17 21 329.68 -52.40 -0.00001308 -25.10 20 271.40 -374.04 -0.00009353 -22.41 19 271.40 -355.07 -0.00008879 -22.52 18 241.31 -449.31 -0.00011239 -14.03 17 241.31 -448.93 -0.00011229 -14.66 16 212.22 -343.29 -0.00008580 0.32 15 212.22 -342.52 -0.00008561 -0.71 14 180.40 -139.06 -0.00003472 19.29 13 180.40 -132.64 -0.00003312 14.92 12 151.83 -62.09 -0.00001550 23.67 11 151.83 -56.56 -0.00001412 22.56 10 121.74 -132.17 -0.00003302 29.74 9 121.74 -128.76 -0.00003217 27.13 8 91.99 -267.06 -0.00006679 22.58 7 91.99 -255.24 -0.00006384 22.04 6 62.98 -292.97 -0.00007330 12.65 5 62.98 -322.23 -0.00008062 12.23 + SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 12 AK1111GCM207 Survey QC - RGS-C pecification Sheet • 9I 4 29.93 -62.58 -0.00001565 3.36 3 29.93 -68.55 -0.00001714 0.76 2 359.21 113.59 0.00002837 -13.58 1 359.21 96.80 0.00002418 -14.06 MBO = -0.01 Gravity Error = 790.28 Scale Factor Uncertainty = 0.00023650 Rate Error = -1.65 POST-JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 17128 269.79 -539.13 -0.00013478 -9.32 17127 269.79 -550.50 -0.00013762 -8.50 17126 224.86 -507.48 -0.00012687 -27.75 17125 224.86 -475.89 -0.00011898 -20.99 17124 45.80 -489.26 -0.00012232 -12.11 17123 45.80 -492.70 -0.00012318 -9.92 17122 1.08 -137.05 -0.00003422 -12.79 17121 1.08 -137.02 -0.00003421 -13.89 17120 329.75 -105.44 -0.00002632 -8.87 17119 329.75 -105.24 -0.00002627 -11.80 17118 300.03 -323.78 -0.00008086 -8.97 17117 300.03 -325.59 -0.00008131 -6.91 17116 270.68 -529.32 -0.00013233 -7.16 17115 270.68 -526.04 -0.00013151 -10.61 17114 238.38 -552.13 -0.00013807 -2.94 17113 238.38 -552.02 -0.00013804 -1.64 17112 210.33 -374.34 -0.00009355 -2.80 17111 210.34 -374.90 -0.00009369 -4.69 17110 180.89 -142.86 -0.00003567 -6.56 17109 180.89 -148.39 -0.00003705 -6.08 17108 149.08 -110.43 -0.00002756 -5.10 17107 149.08 -97.68 -0.00002438 -10.98 17106 118.80 -303.94 -0.00007592 -4.48 17105 118.80 -299.34 -0.00007477 -4.93 17104 90.37 -513.18 -0.00012830 -4.57 17103 90.37 -514.23 -0.00012856 -5.02 17102 60.51 -555.14 -0.00013883 -8.44 17101 60.51 -547.92 -0.00013703 -8.17 17100 30.68 -376.27 -0.00009403 -14.27 17099 30.68 -382.26 -0.00009553 -13.64 17098 358.50 -145.43 -0.00003631 -19.02 17097 358.50 -134.95 -0.00003369 -24.80 17096 270.63 -501.57 -0.00012540 -4.63 17095 270.63 -498.23 -0.00012456 -5.33 17094 223.68 -468.22 -0.00011706 -6.31 17093 223.68 -470.17 -0.00011755 -10.29 17092 44.75 -476.70 -0.00011918 -5.22 17091 44.75 -481.59 -0.00012040 -5.67 17090 0.21 -143.90 -0.00003593 -6.17 17089 0.21 -143.68 -0.00003587 -7.44 17088 329.22 -107.31 -0.00002678 -6.18 17087 329.21 -114.51 -0.00002858 -6.77 17086 300.12 -287.60 -0.00007183 -6.26 17085 300.12 -286.25 -0.00007150 -4.82 17084 269.18 -495.03 -0.00012377 -3.80 17083 269.18 -492.67 -0.00012318 -5.39 17082 239.78 -537.75 -0.00013448 0.55 17081 239.79 -532.88 -0.00013327 -2.34 17080 209.62 -353.31 -0.00008830 -1.13 17079 209.62 -357.24 -0.00008928 -0.42 17078 179.51 -151.91 -0.00003793 0.30 17077 179.51 -153.38 -0.00003829 0.43 17076 151.33 -103.70 -0.00002588 0.03 17075 151.33 -107.19 -0.00002675 2.31 SURV-Q167(OPS SUR-MA-003) 19`"Nov 03/Rev 15 Page 2 of 12 AK1111C4CM207 Survey QC - RGS-specification Sheet • M/Ciatra 17074 121.86 -261.89 -0.00006541 -0.88 17073 121.86 -263.76 -0.00006587 -0.92 ' 17072 90.52 -466.49 -0.00011663 -3.28 17071 90.53 -459.94 -0.00011500 -3.98 17070 61.52 -516.07 -0.00012907 -2.04 17069 61.52 -524.16 -0.00013109 -2.55 17068 31.93 -425.07 -0.00010623 -4.94 17067 31.93 -425.92 -0.00010644 -3.81 17066 358.83 118.79 0.00002967 -2.37 17065 358.83 97.33 0.00002431 -3.20 MBO = -0.16 Gravity Error = -340.03 Scale Factor Uncertainty = -0.00008499 Rate Error = -6.72 INITIALISATION Gyro Compass Reading / Station Raw Inclination Raw Azimuth Abs (ERMeas-ERTheo) 86 10.02 82.56 0.0939 87 10.02 82.62 0.1075 88 10.02 82.74 0.0501 89 10.02 82.86 0.0374 90 10.02 82.98 0.0824 91 10.02 82.96 0.0724 Average 10.02 82.79 0.0739 Tolerance on Average* 0.0813 Standard Deviation 0.00 0.18 0.0264 Tolerance on St. Dev.** 0.10 0.20 0.0364 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance = TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cos1)*J[(cosA*SinI*0.1)2+0.082) °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosl)*J[(CosA*SinI*0.1)2+(0.082/(n-1))) °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 250.72 1850.77 15.89 71.99 0.002 -0.001 0.000 0.001 2 1107.41 3600.73 46.51 69.40 -0.005 0.008 0.006 -0.004 3 1179.77 5501.14 47.53 82.93 0.001 0.002 0.000 0.004 4 1157.61 7401.22 45.90 85.11 0.001 -0.000 -0.001 0.003 5 1200.66 9302.11 43.71 89.37 -0.010 0.004 0.001 -0.002 6 920.73 10061.65 41.30 106.45 0.004 0.000 0.002 -0.001 7 1248.16 9551.85 43.05 90.15 -0.002 0.004 0.001 0.001 8 1205.83 8601.69 43.04 84.77 0.002 -0.007 -0.001 0.001 9 1190.77 7601.69 45.26 85.38 -0.000 -0.005 -0.000 -0.001 10 1206.80 6701.21 45.49 84.80 -0.000 -0.005 -0.001 0.000 11 1287.70 5651.09 46.73 83.09 -0.001 -0.005 -0.001 0.000 12 1157.88 4650.92 49.08 83.78 0.001 -0.006 -0.003 0.001 13 1243.33 3650.64 46.45 69.88 -0.005 0.000 0.004 -0.006 14 1198.48 2550.43 37.19 67.29 0.002 -0.004 -0.001 -0.004 15 978.83 1850.19 16.03 72.14 -0.001 -0.001 0.004 0.002 R SURV-Q167(OPS SUR-MA-003) 19`"Nov 03/Rev 15 Page 3 of 12 AK1111GCM207 Survey QC - RGS-Clkpecification Sheet 16 586.02 1650.37 10.85 87.52 -0.006 0.004 0.007 -0.005 Average -0.001 -0.001 0.001 -0.001 Standard Deviation 0.004 0.004 0.003 0.003 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * I Outrun * I Difference Inrun * I Outrun * I Difference 200.00 0.28 0.26 0.01 166.29 164.03 2.26 300.00 0.30 0.28 0.02 149.17 160.87 -11.70 400.00 0.26 0.29 -0.03 165.36 153.23 12.13 500.00 0.39 0.36 0.03 167.78 154.31 13.47 600.00 0.48 0.43 0.05 152.84 155.85 -3.01 700.00 0.56 0.92 -0.36 103.80 120.20 -16.40 800.00 1.44 1.44 0.00 79.84 82.60 -2.75 900.00 2.62 2.80 -0.18 77.37 79.17 -1.80 1000.00 4.22 4.21 0.01 74.81 77.55 -2.75 1100.00 6.49 6.43 0.06 81.50 80.06 1.44 1200.00 8.71 8.70 0.01 80.72 82.79 -2.08 1300.00 9.43 9.32 0.11 80.80 81.02 -0.22 1400.00 9.89 9.85 0.04 80.01 79.02 0.99 1500.00 9.97 9.93 0.04 83.46 82.24 1.22 1600.00 9.93 9.99 -0.06 85.36 85.74 -0.37 1650.00 10.01 10.02 -0.01 85.93 87.49 -1.55 1675.00 10.34 10.50 -0.16 85.12 86.54 -1.42 1700.00 10.65 10.95 -0.30 84.32 85.14 -0.82 1725.00 11.58 11.91 -0.33 81.11 80.83 0.28 1750.00 12.40 12.96 -0.56 78.01 78.53 -0.52 1775.00 13.26 13.63 -0.37 76.06 76.44 -0.38 1800.00 13.56 14.12 -0.55 75.37 76.23 -0.86 1825.00 14.48 15.04 -0.56 74.50 74.62 -0.12 1850.00 15.76 15.89 -0.14 72.05 72.19 -0.14 1875.00 16.53 16.48 0.04 70.25 71.27 -1.02 1900.00 17.53 17.37 0.16 67.88 68.40 -0.52 1925.00 18.19 18.04 0.15 65.99 67.09 -1.10 1950.00 19.20 18.99 0.22 63.36 63.97 -0.61 1975.00 19.97 19.79 0.18 62.31 63.30 -0.99 2000.00 20.86 20.91 -0.05 62.55 63.64 -1.09 2025.00 22.05 21.94 0.12 63.62 64.91 -1.29 2050.00 22.70 22.74 -0.05 63.86 65.47 -1.61 2075.00 23.17 23.36 -0.19 64.93 66.09 -1.16 2100.00 24.00 24.21 -0.21 65.32 66.62 -1.29 2125.00 24.46 24.58 -0.12 65.65 66.87 -1.21 2150.00 25.05 25.19 -0.14 65.74 67.09 -1.35 2175.00 25.93 25.89 0.04 65.86 66.90 -1.04 SURV-Q167(OPS SUR-MA-003) 19`"Nov 03/Rev 15 Page 4 of 12 AK1111GCM207 • Survey QC - RGS- Pecification Sheetgym/data l 2200.00 26.52 26.51 0.02 65.88 66.88 -1.00 y 2225.00 27.59 27.73 -0.14 66.10 67.31 -1.21 2250.00 28.19 28.37 -0.18 65.95 67.13 -1.19 2275.00 29.18 29.33 -0.15 66.06 67.25 -1.19 2300.00 29.55 29.72 -0.17 66.10 67.25 -1.15 2325.00 30.43 30.61 -0.17 66.06 67.22 -1.16 2350.00 31.11 31.30 -0.19 66.10 67.27 -1.17 2375.00 31.77 31.94 -0.17 66.17 67.29 -1.12 2400.00 32.60 32.80 -0.20 66.11 67.26 -1.14 2425.00 33.13 33.28 -0.16 66.13 67.26 -1.13 2450.00 33.85 34.02 -0.17 66.13 67.24 -1.11 2475.00 34.62 34.82 -0.20 66.10 67.21 -1.10 2500.00 35.48 35.65 -0.17 66.16 67.27 -1.11 2525.00 36.14 36.32 -0.19 66.26 67.31 -1.05 2550.00 36.84 37.02 -0.19 66.23 67.29 -1.06 2575.00 37.75 37.95 -0.20 66.23 67.31 -1.09 2600.00 38.29 38.46 -0.17 66.27 67.32 -1.06 2625.00 39.04 39.20 -0.16 66.07 67.16 -1.09 2650.00 39.62 39.80 -0.18 65.93 66.98 -1.05 2675.00 40.42 40.57 -0.15 65.68 66.74 -1.06 2700.00 41.08 41.27 -0.18 65.45 66.48 -1.03 2725.00 41.90 42.07 -0.16 65.19 66.21 -1.03 2750.00 42.80 42.96 -0.16 65.03 66.06 -1.03 2775.00 43.69 43.87 -0.18 64.90 65.93 -1.04 2800.00 45.04 45.24 -0.20 64.76 65.76 -1.01 2825.00 46.48 46.70 -0.22 64.63 65.58 -0.95 2850.00 48.02 48.23 -0.21 64.71 65.52 -0.81 2875.00 49.12 49.27 -0.15 64.98 65.77 -0.79 2900.00 49.82 49.94 -0.12 65.25 66.02 -0.77 2925.00 50.52 50.63 -0.11 65.56 66.28 -0.72 2950.00 50.98 51.06 -0.08 65.88 66.59 -0.71 2975.00 51.27 51.36 -0.09 66.21 66.97 -0.76 3000.00 51.49 51.57 -0.08 66.32 67.07 -0.75 3025.00 51.16 51.19 -0.03 66.83 67.45 -0.62 3050.00 51.09 51.15 -0.06 67.09 67.76 -0.67 3075.00 51.11 51.20 -0.08 67.18 67.89 -0.72 3100.00 50.87 50.90 -0.03 67.30 68.05 -0.75 3125.00 50.15 50.22 -0.07 67.45 68.13 -0.68 3150.00 49.62 49.60 0.02 67.52 68.13 -0.61 3175.00 48.96 49.00 -0.04 67.60 68.24 -0.64 3200.00 48.08 48.05 0.03 67.85 68.38 -0.53 3225.00 47.01 47.03 -0.02 68.09 68.60 -0.51 3250.00 47.03 47.05 -0.03 68.18 68.69 -0.51 3275.00 47.03 47.06 -0.03 68.56 69.09 -0.52 3300.00 47.17 47.20 -0.03 68.69 69.27 -0.58 SURV-Q167(OPS SUR-MA-003) 19'Nov 03/Rev 15 Page 5 of 12 AK1111GCM207 Survey QC - RGS-C pecification Sheet • gyrodata IEMEMMVEMIMMAMERIIMISOMENIMEMMENREV 3325.00 47.29 47.33 -0.04 68.93 69.45 -0.52 II 3350.00 47.27 47.29 -0.02 69.01 69.54 -0.53 3375.00 47.35 47.38 -0.03 69.14 69.68 -0.53 3400.00 47.16 47.20 -0.04 69.21 69.78 -0.57 3425.00 47.28 47.28 -0.01 69.23 69.72 -0.49 3450.00 47.10 47.13 -0.03 69.30 69.79 -0.50 3475.00 47.10 47.11 -0.01 69.30 69.80 -0.50 3500.00 47.06 47.07 -0.01 69.35 69.79 -0.44 3525.00 47.00 47.02 -0.02 69.39 69.89 -0.50 3550.00 46.96 46.97 -0.01 69.40 69.90 -0.49 3575.00 46.72 46.75 -0.02 69.42 69.91 -0.49 3600.00 46.64 46.65 -0.01 69.40 69.90 -0.49 3625.00 46.41 46.41 -0.00 69.40 69.87 -0.47 3650.00 46.25 46.25 -0.00 69.40 69.86 -0.46 3675.00 46.55 46.60 -0.05 69.38 69.88 -0.51 3700.00 46.33 46.26 0.07 69.39 69.84 -0.46 3725.00 46.24 46.22 0.02 69.39 69.88 -0.50 3750.00 46.27 46.33 -0.06 69.38 69.88 -0.50 3775.00 46.33 46.23 0.09 69.38 69.84 -0.46 3800.00 46.10 46.10 -0.01 69.41 69.83 -0.42 3825.00 45.85 45.83 0.02 69.37 69.80 -0.43 3850.00 45.76 45.76 -0.00 69.42 69.88 -0.46 3875.00 45.73 45.78 -0.05 69.46 69.90 -0.44 3900.00 45.77 45.82 -0.05 69.51 70.09 -0.58 3925.00 45.59 45.40 0.19 69.41 69.88 -0.47 3950.00 45.49 45.51 -0.02 69.74 69.81 -0.07 3975.00 45.38 45.34 0.04 69.77 69.84 -0.07 4000.00 45.23 45.22 0.01 69.80 69.88 -0.08 4025.00 45.09 45.13 -0.04 69.80 69.91 -0.10 4050.00 45.09 45.08 0.00 69.83 69.89 -0.06 4075.00 44.84 44.83 0.02 69.85 69.94 -0.09 4100.00 44.76 44.81 -0.06 69.94 70.01 -0.07 4125.00 44.96 45.06 -0.10 69.96 70.00 -0.04 4150.00 45.30 45.40 -0.10 69.98 70.03 -0.05 4175.00 45.64 45.79 -0.15 70.38 70.82 -0.45 4200.00 46.11 46.20 -0.09 71.93 72.39 -0.46 4225.00 46.41 46.53 -0.12 73.50 73.84 -0.34 4250.00 46.61 46.64 -0.04 75.53 75.94 -0.41 4275.00 46.94 47.04 -0.10 77.11 77.36 -0.25 4300.00 47.36 47.57 -0.20 77.38 77.42 -0.04 4325.00 48.30 48.49 -0.19 77.17 77.24 -0.06 4350.00 49.00 49.36 -0.36 77.19 77.37 -0.18 4375.00 49.94 50.14 -0.20 77.40 77.64 -0.24 4400.00 50.61 50.79 -0.18 78.24 78.55 -0.30 4425.00 50.80 50.73 0.08 79.18 79.79 -0.61 SURV-Q167(OPS SUR-MA-003) 19'Nov 03 J Rev 15 Page 6 of 12 AK1111GCM207 a Survey QC - RGS-specification Sheet 0mdata 4450.00 49.78 49.62 0.16 81.40 81.86 -0.46 11 4475.00 49.02 48.95 0.07 82.80 83.18 -0.38 4500.00 48.94 49.06 -0.12 83.52 83.64 -0.12 4525.00 49.20 49.32 -0.11 83.57 83.72 -0.15 4550.00 49.40 49.50 -0.10 83.63 83.77 -0.14 4575.00 49.12 49.19 -0.07 83.65 83.76 -0.11 4600.00 49.23 49.28 -0.05 83.67 83.80 -0.13 4625.00 49.11 49.26 -0.15 83.71 83.82 -0.11 4650.00 49.17 49.08 0.09 83.68 83.78 -0.10 4675.00 48.81 48.90 -0.10 83.63 83.75 -0.12 4700.00 48.42 48.43 -0.01 83.53 83.64 -0.11 4725.00 48.75 48.61 0.14 83.41 83.61 -0.20 4750.00 49.02 48.88 0.14 83.42 83.63 -0.20 4775.00 49.23 49.11 0.12 83.43 83.62 -0.19 4800.00 49.48 49.35 0.12 83.50 83.72 -0.22 4825.00 49.44 49.29 0.15 83.33 83.67 -0.34 4850.00 49.31 49.18 0.13 83.25 83.64 -0.38 4875.00 48.68 48.68 0.00 83.01 83.65 -0.65 4900.00 48.53 48.64 -0.11 83.28 83.60 -0.32 4925.00 48.32 48.44 -0.12 83.15 83.57 -0.41 4950.00 48.39 48.53 -0.14 83.20 83.63 -0.43 4975.00 48.21 48.34 -0.13 83.18 83.57 -0.39 5000.00 48.10 48.22 -0.13 83.11 83.50 -0.39 5025.00 47.79 47.93 -0.14 83.05 83.44 -0.39 5050.00 47.78 47.93 -0.15 83.00 83.40 -0.40 5075.00 48.04 48.18 -0.14 82.99 83.38 -0.39 5100.00 47.94 48.10 -0.16 82.94 83.32 -0.38 5125.00 47.97 48.19 -0.22 82.85 83.31 -0.46 5150.00 48.19 48.29 -0.10 83.27 83.25 0.01 5175.00 47.96 48.07 -0.11 83.20 83.16 0.04 5200.00 48.02 47.94 0.09 82.96 83.22 -0.26 5225.00 47.62 47.67 -0.05 82.59 83.15 -0.57 5250.00 47.69 47.85 -0.15 82.73 83.09 -0.36 5275.00 47.56 47.73 -0.17 82.74 83.09 -0.35 5300.00 47.35 47.52 -0.17 82.72 83.09 -0.37 5325.00 47.61 47.78 -0.16 82.72 83.07 -0.36 5350.00 47.31 47.44 -0.13 82.69 83.03 -0.35 5375.00 47.44 47.62 -0.18 82.61 82.96 -0.35 5400.00 47.69 47.85 -0.15 82.62 82.98 -0.36 5425.00 47.37 47.53 -0.16 82.59 82.92 -0.33 5450.00 47.25 47.43 -0.18 82.65 82.99 -0.34 5475.00 47.36 47.55 -0.19 83.04 83.02 0.02 5500.00 47.33 47.26 0.07 82.94 83.03 -0.09 5525.00 47.18 47.37 -0.19 82.92 83.00 -0.08 5550.00 46.91 47.08 -0.17 82.91 83.01 -0.10 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 7 of 12 AK1111GCM207 Survey QC - RGS-specification Sheet • ` t/ d ata 5575.00 46.87 47.03 -0.16 82.91 82.99 -0.08 5600.00 46.83 46.97 -0.14 83.33 83.01 0.32 5625.00 46.79 46.84 -0.05 82.76 83.05 -0.29 5650.00 46.47 46.67 -0.20 83.00 83.06 -0.06 5675.00 46.95 46.88 0.06 83.30 83.13 0.17 5700.00 46.73 46.89 -0.16 83.08 83.13 -0.05 5725.00 46.66 46.85 -0.19 83.07 83.10 -0.02 5750.00 46.60 46.77 -0.18 83.04 83.09 -0.05 5775.00 46.65 46.86 -0.22 83.03 83.14 -0.11 5800.00 46.38 46.21 0.17 83.29 83.28 0.01 5825.00 46.04 46.20 -0.16 83.47 83.32 0.15 5850.00 46.23 46.41 -0.17 83.40 83.43 -0.03 5875.00 46.18 46.32 -0.14 83.45 83.47 -0.02 5900.00 45.88 46.04 -0.16 83.40 83.41 -0.01 5925.00 45.74 45.92 -0.17 83.31 83.31 -0.00 5950.00 45.86 45.99 -0.13 83.26 83.26 -0.01 5975.00 45.70 45.88 -0.18 83.20 83.20 -0.00 6000.00 45.62 45.76 -0.14 83.23 83.25 -0.02 6025.00 45.62 45.80 -0.18 83.29 83.28 0.01 6050.00 45.51 45.69 -0.17 83.40 83.40 0.00 6075.00 45.74 45.92 -0.18 83.42 83.45 -0.02 6100.00 45.58 45.74 -0.16 83.54 83.52 0.02 6125.00 45.13 45.32 -0.19 83.67 83.65 0.02 6150.00 45.34 45.53 -0.19 83.71 83.69 0.02 6175.00 45.16 45.31 -0.14 83.77 83.78 -0.01 6200.00 45.39 45.59 -0.20 83.81 83.80 0.02 6225.00 44.97 45.16 -0.19 83.93 83.91 0.02 6250.00 45.10 45.28 -0.18 83.91 83.88 0.03 6275.00 44.89 45.08 -0.19 83.95 83.89 0.06 6300.00 44.67 44.85 -0.17 83.95 83.92 0.03 6325.00 44.95 45.15 -0.19 83.98 83.97 0.01 6350.00 44.99 45.17 -0.18 84.11 84.08 0.02 6375.00 44.97 45.16 -0.20 84.13 84.12 0.01 6400.00 44.98 45.17 -0.20 84.19 84.15 0.04 6425.00 45.00 45.22 -0.22 84.26 84.21 0.06 6450.00 45.17 45.32 -0.15 84.29 84.26 0.03 6475.00 44.82 44.95 -0.14 84.33 84.31 0.03 6500.00 44.47 44.70 -0.22 84.46 84.41 0.05 6525.00 44.92 45.15 -0.23 84.50 84.48 0.02 6550.00 44.91 45.17 -0.26 84.56 84.64 -0.08 6575.00 44.96 44.99 -0.02 84.47 84.65 -0.18 6600.00 44.93 44.97 -0.04 84.49 84.67 -0.18 6625.00 44.89 44.97 -0.09 84.65 84.82 -0.17 6650.00 45.14 45.33 -0.20 84.98 84.90 0.08 6675.00 45.10 45.29 -0.19 84.96 84.87 0.09 SURV-Q167(OPS SUR-MA-003) 19" Nov 03/Rev 15 Page 8 of 12 AK1111GCM207 Survey QC - RGS-specification Sheet • 6700.00 45.27 45.47 -0.20 84.88 84.80 0.07 6725.00 45.21 45.37 -0.15 84.82 84.74 0.08 6750.00 44.75 44.90 -0.14 84.73 84.66 0.07 6775.00 44.53 44.61 -0.08 84.79 84.71 0.08 6800.00 44.21 44.43 -0.22 84.83 84.73 0.11 6825.00 44.33 44.48 -0.15 84.92 84.84 0.08 6850.00 44.56 44.77 -0.20 84.98 84.90 0.08 6875.00 44.53 44.73 -0.20 85.12 85.02 0.09 6900.00 44.77 45.00 -0.23 85.17 85.06 0.11 6925.00 45.04 45.03 0.01 84.98 85.01 -0.02 6950.00 44.71 44.80 -0.09 84.58 84.83 -0.25 6975.00 44.62 44.79 -0.17 84.88 84.93 -0.04 7000.00 44.82 44.98 -0.16 84.90 84.93 -0.03 7025.00 45.18 45.39 -0.20 84.90 84.95 -0.05 7050.00 45.59 45.85 -0.26 84.75 84.89 -0.14 7075.00 45.87 45.81 0.06 85.07 84.85 0.22 7100.00 46.01 46.19 -0.17 85.01 84.86 0.15 7125.00 46.19 46.33 -0.14 84.93 84.83 0.10 7150.00 46.02 46.16 -0.14 84.85 84.84 0.01 7175.00 45.89 45.93 -0.04 85.24 84.78 0.46 7200.00 45.88 45.84 0.05 84.80 84.78 0.02 7225.00 45.67 45.63 0.04 84.95 84.94 0.01 7250.00 45.99 46.02 -0.03 85.03 85.03 0.01 7275.00 46.11 46.07 0.04 85.08 85.07 0.01 7300.00 45.67 45.64 0.04 85.16 85.14 0.01 7325.00 45.79 45.75 0.05 85.20 85.17 0.03 7350.00 45.77 45.76 0.00 85.24 85.21 0.03 7375.00 45.76 45.75 0.01 85.18 85.15 0.03 7400.00 45.67 45.66 0.01 85.12 85.07 0.05 7425.00 45.51 45.50 0.01 85.17 85.12 0.05 7450.00 45.52 45.51 0.01 85.20 85.15 0.05 7475.00 45.57 45.60 -0.02 85.30 85.25 0.05 7500.00 45.53 45.54 -0.01 85.38 85.33 0.05 7525.00 45.59 45.61 -0.02 85.40 85.34 0.06 7550.00 45.48 45.48 -0.00 85.39 85.33 0.07 7575.00 45.47 45.49 -0.01 85.46 85.39 0.07 7600.00 45.20 45.22 -0.02 85.45 85.38 0.07 7625.00 45.32 45.33 -0.01 85.52 85.44 0.08 7650.00 45.07 45.10 -0.03 85.54 85.45 0.09 7675.00 45.03 45.08 -0.05 85.60 85.50 0.09 7700.00 45.19 45.24 -0.04 85.59 85.49 0.10 7725.00 44.90 44.94 -0.04 85.50 85.38 0.12 7750.00 44.94 44.97 -0.03 85.35 85.22 0.12 7775.00 44.68 44.74 -0.06 85.38 85.27 0.11 7800.00 44.63 44.66 -0.03 85.43 85.32 0.11 SURV-Q167(OPS SUR-MA-003) 19`h Nov 03/Rev 15 Page 9 of 12 AK1111GCM207 Survey QC - RGS-*pecification Sheet • .......4......gYrQ'data 7825.00 44.41 44.46 -0.05 85.27 85.14 0.13 • 7850.00 44.19 44.25 -0.07 85.35 85.23 0.12 7875.00 44.35 44.42 -0.07 85.38 85.24 0.14 7900.00 43.98 44.01 -0.03 85.44 85.30 0.14 7925.00 43.70 43.76 -0.06 85.39 85.23 0.15 7950.00 43.87 43.95 -0.09 85.37 85.22 0.16 7975.00 43.99 44.06 -0.07 85.35 85.20 0.15 8000.00 43.85 43.90 -0.05 85.34 85.19 0.15 8025.00 43.36 43.45 -0.09 85.36 85.20 0.15 8050.00 43.57 43.65 -0.07 85.38 85.22 0.16 8075.00 43.27 43.36 -0.09 85.34 85.17 0.17 8100.00 43.10 43.17 -0.06 85.39 85.22 0.18 8125.00 42.74 42.81 -0.08 85.37 85.19 0.18 8150.00 42.46 42.54 -0.08 85.25 85.06 0.20 8175.00 42.41 42.51 -0.10 85.03 84.85 0.17 8200.00 42.77 42.87 -0.10 85.03 84.86 0.17 8225.00 42.91 42.99 -0.08 85.02 84.84 0.18 8250.00 42.72 42.81 -0.10 84.94 84.74 0.20 1 8275.00 42.62 42.71 -0.09 84.85 84.66 0.19 8300.00 42.46 42.54 -0.08 84.81 84.61 0.20 8325.00 42.42 42.52 -0.10 84.73 84.55 0.18 8350.00 42.38 42.49 -0.11 84.71 84.51 0.20 8375.00 41.97 42.09 -0.12 84.68 84.46 0.22 8400.00 42.13 42.22 -0.09 84.64 84.45 0.19 8425.00 42.08 42.20 -0.12 84.68 84.50 0.18 8450.00 42.00 42.08 -0.08 84.55 84.35 0.20 8475.00 41.96 42.06 -0.10 84.59 84.43 0.16 8500.00 41.96 42.06 -0.11 84.69 84.51 0.18 8525.00 42.28 42.51 -0.23 84.84 84.52 0.32 8550.00 42.45 42.44 0.01 84.65 84.51 0.15 8575.00 42.64 42.63 0.01 84.76 84.59 0.16 8600.00 42.99 42.98 0.01 84.88 84.73 0.15 8625.00 42.88 42.89 -0.01 85.07 84.82 0.24 8650.00 42.86 42.88 -0.01 85.15 84.92 0.23 8675.00 42.87 42.87 -0.01 85.13 84.91 0.21 8700.00 43.02 43.03 -0.01 85.25 85.03 0.22 8725.00 42.97 42.97 -0.00 85.39 85.18 0.22 8750.00 43.14 43.13 0.01 85.65 85.46 0.19 8775.00 43.37 43.38 -0.00 85.61 85.39 0.22 8800.00 43.05 43.03 0.02 85.71 85.51 0.20 8825.00 43.08 43.09 -0.01 85.93 85.71 0.21 8850.00 43.22 43.19 0.02 86.01 85.84 0.17 8875.00 43.42 43.39 0.03 86.12 85.95 0.17 8900.00 43.63 43.64 -0.01 86.48 86.29 0.19 8925.00 43.54 43.53 0.01 86.57 86.36 0.21 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 10 of 12 AK1111GCM207 Survey QC - RGS-specification Sheet • gymidata 8950.00 43.73 43.74 -0.01 86.77 86.53 0.24 , . 8975.00 43.52 43.54 -0.02 87.04 86.80 0.24 9000.00 43.63 43.65 -0.01 87.13 86.88 0.25 9025.00 43.48 43.47 0.01 87.16 86.95 0.21 9050.00 43.32 43.31 0.02 87.47 87.27 0.20 9075.00 43.33 43.32 0.01 87.81 87.63 0.18 9100.00 43.34 43.34 0.01 88.02 87.84 0.19 9125.00 43.66 43.68 -0.02 88.35 88.09 0.26 9150.00 43.79 43.83 -0.04 88.28 88.01 0.26 9175.00 43.42 43.46 -0.04 88.10 87.80 0.30 9200.00 43.09 43.08 0.01 89.07 88.88 0.19 9225.00 43.10 43.09 0.02 89.17 88.98 0.19 9250.00 43.29 43.39 -0.10 89.44 88.99 0.45 9275.00 43.61 43.57 0.05 89.29 89.02 0.27 9300.00 43.43 43.47 -0.04 89.37 89.08 0.29 9325.00 43.36 43.39 -0.03 89.59 89.31 0.28 9350.00 43.28 43.30 -0.02 89.87 89.60 0.27 9375.00 43.33 43.33 0.01 89.78 89.59 0.19 9400.00 43.16 43.24 -0.07 90.51 90.53 -0.02 9425.00 42.80 42.82 -0.02 89.66 89.40 0.26 9450.00 43.14 43.26 -0.12 89.89 89.60 0.29 9475.00 42.90 43.05 -0.16 90.06 89.72 0.33 9500.00 43.10 43.24 -0.14 89.69 89.40 0.30 9525.00 42.94 43.09 -0.15 90.28 89.99 0.29 9550.00 42.70 42.88 -0.18 90.71 90.36 0.34 9575.00 42.94 42.90 0.04 89.56 89.53 0.03 9600.00 42.19 42.18 0.00 90.85 90.93 -0.08 9625.00 42.99 43.15 -0.16 91.15 90.64 0.51 9650.00 42.98 43.22 -0.24 88.96 88.74 0.21 9675.00 42.51 42.56 -0.04 91.84 91.46 0.37 9700.00 42.78 42.86 -0.08 91.09 90.90 0.19 9725.00 42.96 43.06 -0.10 89.96 89.53 0.44 9750.00 42.49 42.68 -0.19 90.78 90.50 0.28 9775.00 42.80 43.02 -0.23 92.23 91.93 0.30 9800.00 42.79 43.00 -0.21 89.93 89.69 0.23 9825.00 42.74 42.80 -0.06 91.16 90.95 0.21 9850.00 41.31 41.34 -0.03 92.39 92.40 -0.01 9875.00 41.65 41.77 -0.12 94.95 94.86 0.09 9900.00 42.17 42.20 -0.03 96.53 96.21 0.31 9925.00 41.12 41.18 -0.06 97.29 97.20 0.09 9950.00 41.94 41.78 0.17 99.00 98.85 0.15 9975.00 41.21 41.27 -0.06 100.56 100.48 0.09 10000.00 41.36 41.33 0.03 102.24 102.28 -0.04 10025.00 40.71 40.64 0.07 104.48 104.59 -0.11 10050.00 41.19 41.25 -0.06 105.41 105.30 0.11 SURV-Q167(OPS SUR-MA-003) 19`h Nov 03/Rev 15 Page 11 of 12 AK1111GCM207 SurveyQC - RGS- A specification Sheet 0 . SZASIMENZERNMEMEhittEMEMSZWEeM Average -0.0814 -0.1925 Standard Deviation 0.1095 0.4321 Tolerance for both the Average and the Standard Casing 0.30 Casing 0.50 Deviation Drillpipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19`h Nov 03/Rev 15 Page 12 of 12 AK1111GCM207 w Survey QC - RGS-C nalysis Sheet S1 P gymata 1 SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System I I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 TVD 10.00 Northings 0.00 Eastings 0.00 Latitude 70.2154 Az. Ref: Grid/True true Grid Corrected Y/N? N Description f CALIBRATION Tool Number 1519 Calibration Date 20 Jun 2011 OPERATING TEMPERATURE Calibration range From 50.04 To 120.11 Gyro operating range From 56.37 To 103.78 Spec'- Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job offset Abs dif.cal.post Abs dif.pre.post Spec' Accel Scale 0.000061 0.000237 -0.000085 0.000085 0.000321 Cal/Post-0.00015 Mass Unbalance 1.46 -0.01 -0.16 0.16 0.15 Pre/Post-0.4°/hr INITIALISATION Depth (Approx) 1649.94 No of stns 6 Spec'- Min No. - 6 Azimuth Mean 82.79 Std deviation 0.18 Spec'- Azi SD 0.2° Inclination Mean 10.02 Std deviation 0.00 Spec'- Inc SD 0.1° Earth Horizontal Rate Mean (Abs(meas-theor)) 10.07 Std deviation 0.03 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean -0.001 Std dev' 0.004 Spec's- Mean and SD - 0.333°/hr Residual y gyro bias Mean -0.001 Std dev' 0.003 Spec's- Mean and SD -0.333°/hr TOOLFACE RATE Maximum toolface rate 1236.69 Spec'-400°/sec IN/OUT COMPARISON (AZI' N/A IF INC' <15°) Inclination Difference Mean -0.08 Std dev' 0.11 Spec's- Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean -0.19 Std dev' 0.43 Spec's-Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 2.22 Spec- 5.0/1000 Vertical Divergence/1000 0.80 Spec'- 2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32" Encoder SF I Schlumberger Max Depth (TD) 10059 CCL Corrected No Zero Depth (Rig up) RKB @ 74'AMSL Rezero Depth -2 Given pup joint depth NA Measured PJ NA Strech cor. At TD divided by TD/1000 .5 Spec'- 1.5/1000 _ Dif. Between rigup and rezero depths divided by TD/1000 .2 Spec'- 2.0/1000 f Dif. Between given and meas depth divided by meas/1000 NA Spec' - 2.0/1000 J SURV-Q165(OPS SUR-MA-010)22ntl Jan 2004/Revision 20 Page 1 of 1 AK1111GCM207 r • • gymdata • Survey QC - RGS-CT Acceptance Sheet SEIEVeMMAKRIEVRONAIIMICRINERAMIVAMEMV 11, R ` FIELD AND SURVEY INFORMATION Operator BP Production Field/ Platform Wellhead Well Number 12-06A Survey section From 0.00 ft. to 10059.0 ft. Date 01 Nov 2011 Gyrodata Job No AK1111GCM207 Gyrodata Surveyors Tobias Phillips Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation, after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13"Nov 03/Revision 12 Page 1 of 1 AK1111GCM207 � f Pages NOT Scanned in this Well History' File XHVZE 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. ¢2" ~¢ File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: ~¢;/.~ LT~t¢¢ -~ / Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other - Pages: DIGITAL DATA n OVERSIZED r~ Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by; Dianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bev,dy Di,..a Vi ce.?4C ; ' owe" STATE OF ALASKA 4 1~ LASKA~ AND GAS CONSERVATION COMMISSI~ ~1A`~ ~ ~E'PORT OF SUNDRY WELL OPERATIONS 1. Operations d~ e~~ylfF118 ell ^ Plug Perforations ^ Stimulate^ Other Q TUBING PATCH P f d + er orme : ter Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ 10080'-10112' Change Approved Program Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 192-0540 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20401-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ~ ADLO-028331 ~ PBU 12-06A 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11755 feet Plugs (measured) None feet true vertical 9108 feet Junk (measured) None feet Effective Depth measured 11708 feet Packer (measured) 9672 11162 true vertical 9065 feet (true vertical) 7413 8582 Casing Length Size MD TVD Burst Collapse Structural Conductor 73 20" SURFACE - 73 SURFACE - 73 Surface 2899 13-3/8" 72# L-80 SURFACE - 2899 SURFACE - 2714 5380 2670 Intermediate 9832 9-5/8" 47# L-80 SURFACE - 9832 SURFACE - 7530 6870 4760 Production Liner 2048 7" 26# 13CR80 9664 - 11712 7408 - 9068 7240 5410 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ _ _ - - Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# 13Cr80 49 - 74 49 - 74 4-1/2" 12.6# 13Cr80 25 - 9569 25 - 7337 3-1/2" 9.2# 13Cr80 9571 - 11220 7339 - 8546 Packers and SSSV (type, measured and true vertical depth) 7" Baker H Packer 9672 7413 3-1/2" Otis MHR Packer 11162 8582 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ ~ y !~~ ~, ,~•.- ~ ~ 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: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre t Title Data Management Engineer Signature Phone 564-4944 Date 5/13/2010 12-06A 192-054 PERF ATTA(_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-06A 7/11/92 PER 11,458. 11,478. 8,841.09 8,858.87 12-06A 8/10/92 RPF 11,458. 11,478. 8,841.09 8,858.87 12-06A 10/14/93 APF 11,329. 11,341. 8,727.05 8,737.61 12-06A 10/14/93 APF 11,341. 11,353. 8,737.61 8,748.17 12-06A 7/16/94 APF 11,480. 11,510. 8,860.65 8,887.38 12-06A 7/16/94 APF 11,523. 11,570. 8,898.97 8,940.93 12-06A 10/22/97 APF 11,440. 11,460. 8,825.1 8,842.86 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 • • 12-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY { 5/8/20101'"**WELL SHUT IN ON ARRIVAL***(ELINE-SET PATCH) ~ INITIAL T/I/0= 250/275/0, RU ELINE WITH 3-1/2" BAKER 35 KB PATCH, RIH ***JOB IN PROGRESS, CONTINUED ON 9-MAY-2010*"* 5/9/20101,***JOB IN PROGRESS, CONTINUED FROM 8-MAY-2010*** (ELINE -SET E PATCH) SET 3-1/2" BAKER 35 KB CHROME SINGLE SET PATCH. TOP ELEMENT = 10080', BOTTOM ELEMENT = 10112', DEPTH REFERENCED SLB LDL DATED 15-JAN-1999. PULLED TENSION AFTER PATCH SET, WHILE PULLING SETTING ROD OUT OF PATCH. SSV = C, MV = O, WV = C, SW = C, IA/OA = OTG, FINAL T/I/O = 200/800/100 ***WELL SHUT-IN ON DEPARTURE, JOB COMPLETE"** 5/10/2010t/i/o = 160/250/110. Temp=S1. IA FL (E-Line). AL spool is dropped. IA FL @ 120' (7 bbls). 'SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. NOVP. 5/11/2010 T/I/0=300/250/80 temp=si MIT iA 2400 psi PASS [Eval Tx IA- Secure] '.Rigged up to IA and pumped 14.4 bbls diesel to reach test pressure. IA lost 60 'psi in 15 min's, 30 psi in 2nd 15 min's, for a total loss of 90 psi in 30 min's. Bled back +/- 9 bbls . **Swab, SSV, Wing- Closed, Master, IA, OA valves open** FWHP's= 300/300/80 FLUIDS PUMPED BBLS 1 METH 14 DIESEL 15 Total TREE= 5-118" FMC WELLHEAD =, GRAY ACTUATOR = AXELSON KB. E1.EV = 74.0' BF. ELEV = NA KOP = _ 1400' Max Angle = 52 @ 3000' Datum MD = 11495' Datum TVD = 8800' SS ~5-112" X 4-1/2" XO (-~ 25' 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-j 2899• Minimum ID = 1.83" @ 10086' 3-1/2'" BKR TBG PATCH 4-1/2" TBG, 12.6#, 13-CR..0152 bpf, ID = 3.958" 9569' BKR G2 TIEBACK SLEEVE, ID = 7.50" 9664' 9-5/8" X 7" BKR H PKR, ID = 6.181" 9672' 9-5I8" X 7" BKR HYFLO HGR, ID = 6.181" 9676' 9-518" CSG, 47#, L-80, ID = 8.681" ~-~ 9832' 7" LNR XO FROM L-80 TO 13-CR-80 ~-~ 11043' 3-1i2" TBG, 9.2#, 13-C R, .0087 bpf, ID = 2.992" ~-{ 11220' PERFORATION SUMMARY REF LOG: BRCS ON 06/25/1992 ANGLE AT TOP PERF: 29 @ 11329' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-118" 6 11329 - 11341 O 10114/93 2-1/8" 6 11341 - 11353 O 10114!93 2-1/2" 4 11440 - 11460 O 10122!97 2-518" 4 11458 - 11478 O 07/11/92 2-1/8" 4 11458 - 11478 O 08/10/92 2-1/2" 4 11480 - 11510 O 07/16/94 2-1i2" 4 11523 - 11570 O 07/16/94 7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" ~-i 11755' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/13/81 ORIGINAL COMPLETION 07/12/06 COM/PJC WA V ER SFTY NOTE DELETED 06130/92 RIG SIDETRACK 09/01/06 RRD/PAG SET BKRTBG PATCH 02122/03 JMP/KK WAVER SAFETY NOTE 09/17/09 JL/JMD MIN ID CORRECTION 07/31/05 LDK/PJC CMT OA DWNSQZ 10/02/09 RLNVSV GLV GO (09/07/09) 01/10/06 EZL/PJC UPDATE WA V ER SFTY NOTE (12/18/05) 05/31/06 DTM WELLHEAD CORRECTION SAFETY N01~'""'TBG X IA COMM; LEAK@ GLM #4, 12 -4 6A GLV #4 COULDN'T BE PULLED 05/27/95 OR 01/03/99 `**4- 112" 8 3-1/2" CHROMETBG. 7" CHROME LNR FROM 11043' TO SHOE 2192' 4-1/2" CAMCO BAL-O SSSVN, ID = 3.812" 2598' EST. TOP OF CEMENT CEMENT (07/31/05) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3898 3384 46 TGPDX DMY RK 0 09/07/09 2 6903 5434 45 TGPDX DMY RK 0 09/07/09 3 9381 7200 43 TGPDX DMY RK 0 09/07/09 4 10084 7720 40 FMHO SO RK 28 5 10741 8228 36 FMHO DMY RK 0 6 11085 8516 31 FMHO DMY RKP 0 9571' 4-1 /2" X 3-1 /2" TBG XO, ID = 2.992" 9-5/8" CSG MILLOUT WINDOW 9822' - 9892' (SECTION MILL) 10086'-10119' 3-112" BKR TBG PATCH (09/01!06} 11106' ' 3-112" OTIS X NIP, ID = 2.813"~ ,, ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,f 11162 7" X 3-112" OTIS MHR PKR, ID = 3.875" 11185' 3-112" OTIS X NIP, ID = 2.813" 1120$' 3-112" PARKER SWN NIP, ID = 2.750" 11) 221' I-13-1/2" WLEG, ID = 2.992" 11229' ELMD TT LOGG®07/11!92 11303' 7" MARKERJT. {21') 11708' I->iPBTD PRUDHOE BAY UNR WELL: 12-06A PERMIT No: 1920540 API No: 50-029-20401-01 SEC 18, T10N, R15E, 579' NSL & 19' WEL BP Exploration (Alaska) OPERABLE:Producer 12-06A (PTD~920540) Passed MITIA, no indication~TxIA Page 1 of 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] 2~2 s/~,o Sent: Tuesday, May 11, 2010 11:09 PM To: AK, OPS FS1 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cooper, Katrina N; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS EOC Specialists; AK, OPS FS2 DS Operators; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); 't Mannetje, Davita (Cendris); AK, OPS Gas Lift Engr; Meixueiro, Paulina Cc: Janowski, Carrie; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC) Subject: OPERABLE:Producer 12-06A (PTD #1920540) Passed MITIA, no indication of TxIA All, ,i Producer 12-06A (PTD #1920540) passed a MITIA after installing a patch in the tubing, proving tubing integrity has been restored. The well has been reclassified as Operable. Please let us know if there are any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, October Ol, 2009 8:03 PM ~~ , ~ $~ Uu 4s To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; 'Regg, James B (DOA)'; Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>; 'Maunder, Thomas E (DOA)'; GPB, Gas Lift Engr Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 12-06A (PTD #1920540) TxIA Comm secured with kill weight fluid All, Well 12-06A (PTD #1920540) failed an MITIA after dummy gas lift valves were set. Plans progress to continue diagnostics and restore tubing integrity by setting a patch. Due to this well's proximity to another well currently being sidetracked, well 12-06A was secured with kill weight fluid. The well has been reclassified as Not Operable and shall remain shut-in until tubing integrity is restored. Please let us know if there are any questions. Thank you, Anna dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 5/12/2010 OPERABLE:Producer 12-06A (PTD~920540) Passed MITIA, no indication~TxIA Page 2 of 2 From: NSU, ADW Well Integrity Engineer Sent: Saturday, September 05, 2009 1:32 PM To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; Regg, James B (DOA); Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>; Maunder, Thomas E (DOA); GPB, Gas Lift Engr Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 12-06A (PTD #1920540) Sustained Casing Pressure due to TxIA Comm All, Well 12-06A (PTD #1920540) is an artifically lifted well and has been found to have TxIA communication allowing for sustained casing pressure on the IA. The wellhead pressure readings were tubing/IA/OA equal to 830/1800/90 on 9/4/09 when a TIFL failed confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while further diagnostic work is completed. The plan forward includes: 1. DHD: TIFL -FAILED 2. Slickline: DGLVs 3. Fullbore: MITIA to 2500 psi 4. Slickline: Reset live GLVs if the MITIA passes A TIO plot and wellbore schematic have been included as reference. File: 12-06A TIO Plot.doc » Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 5/12/2010 10/ 16/09 stl~'~~I~6~ ~r~ Alaska Dafa & Consulting Services 2525 Gembell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~ D~~. ~ ~ ~oa~ Log Description N0.5418 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD Pt-25 AP30-00063 INJECTION PROFILE 10/0209 1 1 W-01A 12-06A 82NJ-00026 AZCM-00043 MEMORY GLS LDL 10/02/09 10/03/09 1 1 1 1 W-36 E-35A AV7H-00028 B2NJ-00027 PROD PROFlLE W/GL MEM CEMENT BOND LOG 09/29/09 10!03/09 1 1 1 1 12-34 Z-07A AYS4-00104 AYS4-00101 INJECTION PROFILE PRODUCTION PROFILE 10/11/09 10/08/09 1 1 1 1 15-18A D5-18A 62WY-00015 B04C-00069 MEM PROD PROFILE SCMT 07/01/09 07/30/09 1 1 1 1 U-OSA P-07A B146-00068 AWJI-00051 USR MEM P O PROFILE ~ 08/17/09 10/09!09 1 1 1 1 09-03 AZCM-00044 PRODUCTION LOG 10/10/09 1 1 1-45/0-26 S-134 82NJ-00032 AWLS-00039 MEM LDL USIT 10/10/09 09/28!119 1 1 1 i V-105 83SQ-00026 (PROF 10!03/09 1 1 Well Job # BP Exploration (Alaska) Inc. Pefrotechnical Data Center LR2-1 900 E. Benson 81vd. /~~ Ma~& ~~°J Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 4DD Anchorage, AK 99503-2838 i~ NOT OPERABLE: 12-06A (PT~1920540) TxIA Comm secured with ~weight fluid Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] -~ ~~~I~»~ Sent: Thursday, October 01, 2009 8:03 PM '~~`~ To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; Regg, James B (DOA); Schwartz, Guy L(DOA); Maunder, Thomas E(DOA}; GPB, Gas Lift Engr Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 12-06A (PTD #1920540) TxIA Comm secured with kill weight fluid =1- '~ All, .~~' Well 12-06A (PTD #1920540) failed an MITfA after dummy gas lift vaives were set. Plans progress to continue diagnostics and restore tubing integrity by setting a patch. Due to this well's proximity to another well currently being sidetracked, well 12-06A was secured with kill weiqht fluid. The weli has been reclassified as Not Operable and shall remain shut-in until tubinq intearitv is restored. Please let us know if there are any questions. Thank you, Anna ~Dude, ~.~. (alt Torin Roschinger) ,~, } ~ f ~ Well Integrity Coardinatc~r ~``°''~,;~~1~'~~ ~`~~ .': ~. ~~~`r GP~ 1~lells (~roup Phone: (907} 659-51~2 Pager: {907j 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, September 05, 2009 1:32 PM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; Regg, James B (DOA); Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>; Maunder, Thomas E(DOA); GPB, Gas Lift Engr Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 12-06A (PTD #1920540) Sustained Casing Pressure due to TxIA Comm All, Well 12-06A (PTD #1920540) is an artificaily lifted well and has been found to have TxIA communication allowing for sustained casing pressure on the IA. The wellhead pressure readings were tubing/IAlOA equal to 830/1800/90 on 9/4/09 when a TIF~ failed confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while further diagnostic work is completed. The plan forward includes: 1. DHD: TIFL - FAILED 2. Siickline; DGLVs 3. Fullbore: MITIA to 2500 psi 4. Slickline: Reset live GLVs if the M1TIA passes A TIO plot and welibore schematic have been included as reference. « File: 12-06A TIO Plot.doc » ~ 11 /4/2009 NOT OPERABLE: 12-06A (PT~1920540) TxIA Comm secured with ~weight fluid Page 2 of 2 Please let us know if there are any questions. Thank you, Anna ~u6e, ~.~. ~alt Torin Roschinger) Well Integrity Co~rdinator GPB ~'Uells Group Phone: (907} 659-51fl2 Pager: (907) 659-5100 x1154 11 /4/2009 PBU 12-06A PTD 1920540 9/5/2009 TIO Pressures _ a,oo~ ; 3,000 2,000 1,000 06l06I09 06I13I09 06I20109 06l27I09 07104109 07I11I09 07I181~9 07125l09 08i01l09 OS10$!09 08115109 08I22/09 Q8,~29109 .. .. ~ Tbg -~- IA I -~ OA ~ OOA - + OOOA ~I ~ -~ 0n 1! u ~ TREE= 5-1(8" FMC WELLHEAD = GFt4Y ACTUATQR - ~......... AXELSON KB. ElEV = ~BF. ELEV = .~ ____~.. 74.0' ~ _ ~NA KOP = _ 1400' Max Angle - _ _~ 52 @ 3000' .,_,~ Datum MD = .... 11495' Datum ND = 8800' SS ~ ~ 5-112" X 4-1/2" XO ~-E 25~ ~ 13-3I8" CSG, 72#, L-80, BD = 12.347° ~ 28g9' nnanamum'D = 2.750~~ @ 11208° 3-1/2" Parker SWN Nipple I 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.95II" ~~~g' BKR C-2 TIEBACK SLEEV E, ID = 7.50" 9664' 9-5/8"' X 7" BKR H F~R, ID = 6.181" 9672' 9-5i8" X 7°' BKR HYF~O HGR, ID = 6.181" g~7~' 9-5(8" CSG, 47#, L-80, ID = 8.681 °~-~ 9832~ 7" LNR XO FROM t~-80 TO 13-CR-80 ~-{ 11043' 3-112" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" ~-j 11220' PERFORA7K}N SUMMARY REF LC?G: BHCS ON Q6125t1992 ANGLE AT TC?P F'EftF: 29 @ 11329' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1!$" 6 11329 - 11341 O 10114/93 2-1/8" 6 11341 - 11353 C? 10/14/93 2-1/2" 4 11440 - 11460 0 10/22/97 2-518" 4 1145$ - 1147$ Q 07/11/92 2-1t$" 4 11458 - 11478 O 08l10l92 2-1/2" 4 11480 - 11510 O 07i16/94 2-112" 4 11523 - 11570 O 07J16/94 7" LNR, 26#, 13-CR-8Q, .0383 bpf, ID = 6.276" ~--~ 11755' 11221' -~3-1/2" WLEG, ID=2.992" ~ '11229~ ELMD TT' LOGGFJ.~ 07l11l92 - 11343~ 7" MARKERJT. (21'}, 11708~ I-') ~TD DATE REV BY COMMENTS DATE REV BY CQMMENTS 04/13/81 ORIGINALGOMPLEi'ION 07/12/06 COMlPJC WAIVERSFTYNOTEDELEfED 06J30192 RIG SfDETRAGK 09/01/06 RRD/PAG SET BKR TBG PATCH 02/22/03 JMPIKK WAIVER SAFEIY NOTE 09l21108 GJFISV GLV GO {09/19/08} 07131/05 LQK/PJC CMT OA DWNSG2Z 01/10/06 QLlPJG UPDATE WANER BFTY NOTE (12l18/05) 05/31/06 DTM WELLHEAD CARRECTION PRUDHOE BAY UNIT WEL.L: 12-06A PERMff No: ~1924540 API No: 50-029-20401-01 SEC 18, T10N, R15E, 579' NSL & 19' WEL BP Exploration (Alaska) 2192' 4-1/2" CAMCO BAL-O S5SVN, iD = 3.812" 2598~ EST. TOP OF GEMENT CEMENT (47/31l05) GAS LIFT MANDRELS ST MD 7VD DEV TYPE VLV LATCM PORT DATE 1 3898 3384 4B TGPDX DOM RK 16 09/19/08 2 6903 5434 45 TGPDX DOM RK 16 09/19/08 3 9381 72Q0 43 TGPDX SO RK 22 q9J19/08 4 10084 7720 4b FMHO SO RK 28 5 10741 &22& 36 FMHO DMY RK 0 6 11085 8516 31 ~MHO DMY RKP 0 9571` 4-1(2" X 3-1/2" TBG XO, ID = 2.992" I 9-5/8" CSG MILLdUT WINDOW 9822' - 9892' (SECTION MILL} 10t1~ fid'-1~119' ~ 3-1/2" BKRTBG PATCH (09101J06) --~ ---- - 11106' 3-~i2° OTIS X NIP, ~a = 2.s~3^~ 11162' 7" X 3-1/2" OTIS MHR PKR, ID = 3.875" 11185' 3-1/2" OTI5 X NIP, ID = 2.$13" 1120$' 3-1l2" PARKER SWN NIP, ID = 2.750" 1. Operations Performed: Repair Well 00 Stimulate 0 MIH.;nOrage Abandon 0 Plug PerforationsD OtherD Alter CasingO Pull TubingD Perforate New Pool 0 WaiverO Time ExtensionO Change Approved ProgramO Operation ShutdownD Perforate 0 Re-enter Suspended WellO 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 192-0540 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphiCD ServiceD 50-029-20401-01-00 7. KB Elevation (ft): 9. Well Name and Number: 74.00 12-06A 8. Property Designation: 10. Field/Pool(s): ADL-028331 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11755 feet true vertical 9106.7 feet Plugs (measured) None Effective Depth measured 11708 feet Junk (measured) None true vertical 9064.5 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 20" 91.5# H-40 53 - 126 53.0 - 126.0 1490 470 SURFACE 2847 13-3/8" 72# L-80 52 - 2899 52.0 - 2713.7 4930 2670 SURFACE 9771 9-5/8" 47# L-80 51 - 9822 51.0 - 7522.6 6870 4760 PRODUCTION 2091 7" 26# 13Cr80 9664 - 11755 7407.5 - 9106.7 7240 5410 S('^M~\!~O ~ C 2f\fW\ .'> _vU Perforation depth: \;.:;'¡' l'#JÇ'~»; '. ;', '~,~" Measured depth: 11329-11353,11440-11460,11458-11478, 11480-11510, 11523-11570 True vertical depth: 8825-8843,8841-8859,8861-8887,8899-8941 Tubing ( size, grade, and measured depth): 5-1/2" 17# 13Cr80 @ 49 - 74 4-1/2" 12.6# 13Cr80 @ 74 . 9569 3-1/2" Baker Chrome Patch @ 10084 - 10119 Tubing Patch Packers & SSSV (type & measured depth): 7" Baker H Packer @ 9672 3-1/2" BKR One-Set Top PKR @ 10084 3-1/2" BKR One-Set BTM PKR @ 10119 7" Otis MHR Packer @ 11162 4-1/2" Camco BAL-O SSSVN @ 2192 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Daily Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 368 820 2381 --- 256 Subsequent to operation: SI 0 0 --- 460 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentOO ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to th~ øFt~dge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr "-,OCT 1 7 2006 N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature .A1ë:: d ~..~ ¡¿JJ -r( I Phone 564-5174 Date 10/13/06 Form 10-404 Revised 4/2004 Uì\ I ;' I ¡ " rì. L . . RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 7 2006 REPORT OF SUNDRY WELL OPERA TIOrt9<a Oil & Gas Cons. Commission . . 12-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/04/2006 T/I/0=1910/700/50. Temp=SI. WHP's, TBGP & IA FL (post-TIFL). TBG FL @ 5311'. IA FL @ 7031'. WHP's remain unchanged. 09/03/2006 TII/O = 1910/700/50. Temp = SI. WHPs, IA FL (post TIFL). Tubing pressure increased 40 psi overnight. lAP increased 30 psi overnight. No change in OAP. IA FL rose 10' to 7045' (between sta #2 & #3). 09/02/2006 T/I/O = 2030/1990/50. Temp = SI. TIFL INCONCLUSIVE (Post Patch). IA FL @ 6280' (between sta #1 & #2). Bled lAP to 670 psi in 4 hrs. Tubing pressure decreased to 1870 psi. IA FL dropped to 6490'. SI, monitored for 1 hr. No changed in Tubing pressure. No change in lAP. IA FL dropped to 7055' (between sta #2 & #3). Final WHPs = 1870/670/50. 09/01/2006 SET BAKER 3.5" TUBING PATCH FROM 10084'-10119' AS PER PROGRAM. SLACKED OFF TO CONFIRM SET. DEPTH CORREDCTED TO SLB PATCH SETTING RECORD 2- 5-99. PATCH COVERING GLM #4. *****JOB COMPLETE***** 08/30/2006 T/I/O= 2050/2000/60. Temp= SI. WHP's, TBG & IA FL (E-Line). AIL line SI @ lateral. Tubing FL @ 3120'? IA FL @ 6297'? between sta# 1 & 2. 08/16/2006 ATTEMPT TO PULL RK-DGLV FROM ST#4 (40mins), NO LUCK OVER SHOT BUSTED ONE OF THE DOGS. PULLED EMPTY C-SUB FROM 11198' SLM. DRIFTED W/ 10' x 2.80" DUMMY GUN TO 10,500' SLM, NO PROBLEMS. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** 08/15/2006 LRS PUMPED 150 BBLS HOT CRUDE FOR BRUSH AND FLUSH, BRUSH TO 11,150' SLM W/ 3.5" BLB. JAR ON STA 4 W/ GLOBAL KEPT SLIPPING OFF. PLANT OVERSHOT ON St# 4. TOTAL TIME JARRING W/ALL TOOLS= 1 HR 50 MINS. 08/15/2006 TII/0=2300/21 00/0 Assist Slickline. Pumped 5 bbls neat meoh, 150 bbls of crude @ 190* down tubing. FWHP's=820/2260/160 08/14/2006 Assist Slickline. Pump as directed.--Pump 37 bbls hot diesel down tbg. Slowly heated from 100 to 175 degrees. 08/14/2006 ** WELL SHUT IN UPON ARRIVAL ** {fish glv} ATTEMPTED TO SET C-SUB, ASPHALTINE OBSTRUCTION @ 10077' SLM. RAN 21/4" DD BAILER TO CLEAR OBSTRUCTION. BECAME STUCK WHILE IN HOLE W/BAILER. LRS PUMPED HOT DIESEL TO FREE UP TOOLS. RAN GAUGE RING AND SCRATCHER TO CLEAN UP BAD SPOTS. SET 31/2" WHIDDON C-SUB @ 11198' SLM. ATTEMPT TO RIH TO PULL ST#4, WIRE STICKING IN STUFFING BOX. LRS ENROUTE TO B&F TBG. 08/09/2006 TIO= 2070/2180/50. Monitor WHPs Bleed Tbg & lAP (DSO call in). AIL closed at lateral. 07/23/2006 T/I/0=1850/1930/50 Temp=S/1 WHP's (Eval high lAP, FO call in 7/22) AIL is shut in at lateral valve/open at casing valve.Well is a shut in trouble well - Waiver cancelled 7/12/06 due to failed MIT-OA. Has known T x IA comm. @ glm #4. Page 1 . . 12-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/11/2006 T/1/0=220/1640/100 temp=HOT MIT OA to 3000 psi (FAILED) (UNABLE to establish LLR amt to small) (reg. compl) Pressured OA to 3000 psi with 1.3 bbls crude. OA lost 530 psi in 15 minutes. Second test pumped up OA to 3000 psi with .2 bbls crude. OA lost 500 psi in 15 minutes. Bled pressure down. FWHP's= 340/1640/0 07/09/2006 BOPD: 368 BWPD: 2,381 MCFPD: 2,823 AL Rate: 2,003 FLUIDS PUMPED BBLS 4 Diesel --- PT Surface Equipment 5 Methanol 37 Diesel 152.5 Crude 198.5 TOTAL Page 2 I' TREE= W8...LHEAD = ACTUA TOR = · KB. 8...EV = BF. 8...EV - KOP= Max Angle = Datum MO = Datum TVD = 5-1/8" FMC GRAY AX8...S0N 74.0' NA 1400' 52 @ 3000' 11495' 8800' SS 12-06A SAFETY ES: ***TBG X IA COMM; LEAK@ GLM #4, GL V #4 COULDN'T BE PULLS> OS/27/95 OR 01/03/99.-4- 1/2" & 3-1/2" CHROMETBG. 7" CHROMELNR FROM 11043' TO SHOE 5-1/2"X4-1/2"XO I 25' \ J 2899' ~~ 2192' 1-14-1/2" CAMCO BAL-O SSSVN, ID = 3.812" 1 2598' 1-1 EST. TOP OF CEMENT CEMENT (07/31/05) I 113-3/8" CSG, 72#, L-80, ID = 12.347'" 1-J I . Minimum ID = 2.750" @ 11208' 3-1/2" Parker SWN Nipple ~ ST 1 2 3 4 5 ............ 6 "r MO 3898 6903 9381 10084 10741 11085 TVD 3384 5434 7200 7720 8228 8516 GAS LlFTMANDR8...S DEV TYPE VLV LATCH PORT 46 TGPDX RK 45 TGPDX RK 43 TGPDX RK 40 FMHO RK 36 FMHO RK 31 FMHO RKP DATE 14-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I BKR C-2 TIEBACK SLEEVE, ID = 7.50" H 19-5/8" X 7" BKR H PKR. ID = 6.181" I...... 19-5/8" X 7" BKR HYFLO HGR, ID = 6.181" I...... 9569' I 9664' 9672' 9676' I l J---- >< --i 9571' 1-14-1/2" X 3-1/2" TBG XO, ID = 2.992"' I 7" LNR XO FROM L-BO TO 13-CR-SO H 11043' I \' 9-5/8" CSG MILLOUT WINDOW 9822' - 9892' (SECTION MILL) 11 I 10084'-10119' -13-1/2" BKRTBG PATCH (09/01/06) I '\ \, ' 11106' 1- 3-'J2" QllS x NP, D= 2.813" I ~ 11162' -17"X3-1/2"OTISMHRPKR.ID=3.875" ~\ I 11185' -13-1/2"OTlSXNIP,ID=2.813" \ \ 11208' H3-1/2" PARKER SWN NIP, ID = 2.750" I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 9832' 13-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" I 11220' 11221' 1-13-1/2" WLEG,ID= 2.992"1 I 11229' H8...MDTrLOGGED07/11/92 1 PERFORA TION SUMMARY REF LOG: BHCS ON 06/25/1992 ANGLE AT TOP PERF: 29 @ 11329' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11329-11341 0 10/14/93 2-1/8" 6 11341-11353 0 10/14/93 2-1/2" 4 11440-11460 0 10/22/97 2-5/8" 4 11458 - 11478 0 07/11/92 2-1/8" 4 11458-11478 0 08/10/92 2-1/2" 4 11480-11510 0 07/16/94 2-1/2" 4 11523-11570 0 07/16/94 11303' -17" MARKERJT. (21') I ---I 11708' H PBTD I 17" LNR, 26#, 13-CR-SO, .0383 bpf, ID = 6.276" H 11755' 1----- . DATE 04/13/81 06/30/92 02/22/03 07/31/05 12/09/05 12/31/05 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK JMPlKK WAIVER SAFETY NOTE LDKlPJC CMT OA DWNSQZ DAV/PJC SETTIP@ 11208 IIt1OR/TLH TIP PULLED (12/24/05) DA TE REV BY COMMENTS 01/10/06 EZLlPJC UPDATEWAIVERSFTY NOTE (12/18/05 05/31/06 DTM W8...LHEAD CORRECTION 07/12/06 COM'PJC WAIVER SFTY NOTE D8...ETED 09/01/06 RRD/PAG SET BKR TBG PA TCH PRUDHOE SA Y UNIT W8...L: 12-06A PERMIT No: '1920540 API No: 50-029-20401-01 SEe 18, T1 ON, R15E, 579' NSL & 19' W8... BP Exploration (Alaska) '\ STATE OF ALASKA') ALA~ ..1\ OIL AND GAS CONSERVATION COMtvl,-,SION SEP 1 f- 20 _ REPORT OF SUNDRY WELL OPERATIO~SL" ,~,. J¡ 05 , ".".i,,~I{.:, duJ f" "'0 1. Operations Abandon D Repair Well EI Plug Perforations D Stimulate 0 \, '·':'t)tnér~E:rm'.18" Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time ExtenSi~¡:rE21:ì',:Jt'i:; Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 ,,' 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development l~ Exploratory [' 192-0540 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20401-01-00 7. KB Elevation (ft): 9. Well Name and Number: 74 KB 8. Property Designation: ADL-028331 11. Present Well Condition Summary: Total Depth measured 11755 true vertical 9106.68 Effective Depth measured 11708 true vertical 9064.51 Casing Conductor Surface Production Liner Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# 13CR80 Length 73 2847 9771 2091 Perforation depth: Measured depth: 11329 - 11353 True Vertical depth: 8727.05 - 8748.17 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 244 263 x 12-06A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 53 - 126 52 - 2899 51 - 9822 9664 - 11755 TVD Burst Collapse 53 - 126 1490 470 52 - 2713.69 4930 2670 51 - 7522.62 6870 4760 7407.52 - 9106.68 7240 5410 11440 - 11460 11480 -11510 11523 - 11570 8898.97 - 8940.93 11458 - 11478 8841.09 - 8858.87 8860.65 - 8887.38 8825.1 - 8842.86 5-1/2" 17# 4-1/2" 12.6# 13Cr80 13Cr80 49 - 74 74 - 9569 7" Baker H Packer 3-1/2" Otis MHR Packer 9672 11162 -$Cl~NNEr:\: SEP 2, 1 2005 RBDMS 8Ft SEP 1 6 Z005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 693 2832 500 1031 2789 0 15. Well Class after proposed work: Exploratory r Development ¡;¡ 16. Well Status after proposed work: Oil P' Gas í WAG r Tubing pressure 300 239 Service r WDSPL r GINJ r WINJ í 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: 305-201 Contact Sharmaine Vestal Printed Name Sharmaine Vestal 7~ Signat~ Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 9/14/2005 OR\G\NAL Submit Original Only ) ) 12-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY I 6/24/2005 OA Down Squeeze Pump 29 bbls cement, displaced with 5 bbls water and 129 bbls of crude 6/24/2005 T/I/O= 300/1500/500 Well flowing on arrival; -OA Down Squeeze- Pump 167 bbls of crude down the OA. FWP= 300/1440/400 6/28/2005 Continued on 6-29-05 Moved unit to 12-06 for MITxO.A. Wells support is squaring up well house. 6/29/2005 Continued from 6-28-05 T/I/O=750/1660/50 Pumped 62 bbls diesel for MITxO.A. @ 3000psi. (post squeeze) (FAILED) After 62 bbls did not catch pressure. FWHP= 750/1660/400 7/4/2005 TIO = 1980/1975/90. Temp = SI. OA FL (for FB). OA FL @ surface, bled one gallon to metal bucket to confirm FL. Note: DSO brought well on line at my departure. 7/21/2005 T/I/O=SSV/1980/100 Injectivity test on OA (Prep for downsqueeze) - Pump 192 bbls crude down OA @ 5 bpm to establish injectivity prior to OA downsqueeze Final WHP's=SSV/1980/350 ~25~005JOBPOSTPONED 7/31/2005 T/I/O Shut-ln/2000/300 OA down sqz.Pumped 10 bbl Meth spear, 10 bbl's DS CW101 surfactant, 255 bbl's fresh water, 29 bbl's 15.7# Arctic set cement, 5 bbl's fresh water, and 129 bbl's cold crude. Final WHP's T/I/O Shut-ln/2000/425. 7/31/2005 T/I/O=2020/2000/450 Assist SLB pumpers w. OA downsqueeze. Pumped 129 bbls of crude down the OA Final WHP's = 2030/2000/450 8/3/2005 TII/O=SSV/2000/20 MIT OA **FAILED**(Post Squeeze) - Pumped 25 bbls crude and could not pressure OA, Pumped 45 bbls crude to establish LLR, 5 BPM @ 750 psi Final WHP's=S/1 /2000/350 8/4/2005 T/I/O = SSV/21 00/220. SI. OA FL (Post MITOA). OA FL @ Surface. Note: SSV supply line disconected at control panel. 8/6/2005 T/I/O=2180/21 00/150. Temp=SI. TIFL FAILED, (SCP list 8/03/05). AIL line shut at lateral, isolated AIL line from IA and bled down to 200 psi monitored for 15 min. with no increase in pressure. InitiallA FL @ 9628' (between sta 3 & 4)(515 bbls). Bled lAP from 2100 psi to 1100 psi in 2 hours, IA FL inflowed to 5809' (3819'). TP decreased 440 psi and OAP increased 30 psi. Monitored lAP for 1 hour, TP increased 10 psi, lAP increased 20 psi and OAP increased 10 psi. IA FL inflowed to 5695' (110') Final WHP's=1750/1120/190. 8/7/2005 TII/O 1800/1120/300 OA DOWN-SQUEEZE Pump 10 bbls Meth, 10 bbls Fresh Water w/CW101 Surfactant, 255 bbls Fresh Water Flush, 60 bbls 11# Lite Crete Cement, 5 bbls Fresh Water Flush, 48 bbls Cold Crude. Final T/I/O 1800/1130/435 8/7/2005 T/I/O=1800/1100/300 Assist w/CEMENT SQUEEZE Pumped 48 bbls crude. Final WH p's= 1850/1140/425 8/9/2005 TII/O = 1840/1160/0. MIT-OA to 2400psi PASSED on the 4th attempt. Pumped 1.5 bbls crude to achieve test pressure. Lost 80 psi / 1 st 15 min and 40 psi / 2nd 15 min, for a total loss of 120 psi in 30 min. Final WHP's = 1840/1160/0 FLUIDS PUMPED BBLS 20 Methanol 20 CW101 Surfactant 520 Fresh water 89 Cement 344 Crude 993 TOTAL ií' \ ~u~\1r¡t ¡,'7";"!i ¡'i= I ':: I ' iii:¡¡'~ '\. !~; j .¡ : ""~- -...... ',"", ~'l .'--'~ -., l,\ I ' I , : 1 : ;' ~ L" ':-.J ' ;.-:J -....... FRANK H. MURKOWSKI, GOVERNOR , '-.' " 1 '__,. :-; ........J :::.r.-_..... ':"'cJ' \.......:. ....._../ : . .; I ' , ':_," ,-.I '."'; AItASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ()" , ,', f),.;~, ,,~~5~c hd" v Re: ._', " '. f-/Ñ, ~~ ?J)H5 Prudhoe Bay 12-06A SCf~NNE\) JUL l~, Sundry Number: 305-201 Dear Ms. Julian: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision Superior Court unless rehearing has been requested. DATED this~day of July, 2005 Encl. bp ~.)",,>, ~;,; .."':::i, ",,' '" ," ..'.'.:,',:,~, ',:.'.....,' { ~, RECEIVED JUL 2 1 2005 July 19, 2005 Alaska Oil & Gas Cons. Commission Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RE: Sundry Notice for 12-06A OA Downsqueeze BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain a;:Vff1je,..o¡ waiver for well 12-06A. L~/' Procedure includes the following steps: Step Type P roced u re 1 F Establish OA LLR (pre-OA down squeeze) 2 F OA cement down squeeze (' 3 F MIT OA after WOC / DS12-06A is an artificially lifted producer which requires a waiver for TxlA . communication. There was an OA down squeeze completed on 06/24/05 but the /' subsequent MITOA did not pass. The OA FL was depressed to 640 feet prior to the first OA down squeeze attempt. In order to waiver the well for production, an OA down squeeze must be performed. This program is designed to pump a column of cement . from the shoe to approximately 500 feet above the shoe for waiver compliance. Please /' make any changes to this procedure in compliance with the new down squeeze job design work being done. The procedure includes the following major steps: 1. DHD Shoot fluid levels and record WHP's / 2. F Establish LLR on OA 3. DHD Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. 4. F OA cement down squeeze / 5. F MIT OA after waiting on cement (WOC). ' /' If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. Sincerely, C - C A ~~ ()~~ Wnnifer Julian Wells Engineer ( STATE OF ALASKA it ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons:. \,¡umm¡;¡J.(¡ D Anc.horage Operation Shutdown PerforateD Waiver U Other 0 Plug Perforations D StimulateD Time Extension D Perforate New Pool D Re-enter Suspended Well 0 4. Current Well Class: / 5. Permit to Drill Number: I 192-0540 // Development ŒJ Exploratory D Stratigraphic D Service D 9. Well Name and Numb,: 12-06A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11708 8990.5 Size MD TVD top 53 52 51 9672 1. Type of Request: Abandon 0 Suspend 0 Alter Casing D Repair Well 00 Change Approved Program 0 Pull Tubing 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 74.00 KB 8. Property Designation: ADL-028331 11. Presen1 Total Depth MD (ft): 11755 Casing Total Depth TVD (ft): 9106.7 Length CONDUCTOR SURFACE PRODUCTION LINER 73 2847 9771 2083 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# 13Cr80 Perforation Depth MD (ft): 11329 - 11353 I 11440 - 11478 11480 - 11510 11523 - 11570 Perforation Depth TVD (ft): 8727 - 8748 8825 - 8859 8861 - 8887 8899 - 8941 Packers and SSSV Type: 7" Baker H Packer 3-112" Otis MHR Packer 4-1/2" Camco BAL-O SSV Nipple 12. Attachments: Description Summary of Proposal Œ] Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: July 31,2005 c¡Jf 7- t.S'-~ / bottom top bottom 126 53.0 126.0 2899 52.0 2713.7 9822 51.0 7522.6 11755 7413.4 9106.7 W 6/'" ,/2. S IlJ..'OS RECE'\Ir=r'~~; JUL 2 1 Z005 6. API Number /' 50-029-20401-01-00 Plugs (md): None Burst Junk (md): None Collapse 1490 4930 6870 7240 470 2670 4760 5410 Tubing Size: Tubing Grade: Tubing MD (ft): 5-112 " 17# 13Cr80 49 74 4-1/2 " 12.6 # 13Cr80 74 9569 3-1/2 " 9.2 # 13Cr80 9569 11220 Packers and SSSV MD (ft): 13. Well Class after proposed work: 9672 11162 2192 " /1 Exploratory D DevelopmentŒ] 15. Well Status after proposed work: Oil ŒJ I GasD PluggedD 16. Verbal Approval: Date: WAG D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature ~::;~UI~ Service D Abandoned 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Jennifer Julian Title Phone Wells Engineer 564-5663 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Other: BOP TestD Subsequent 0 Approved by' Form 10-403 Revised 11/2004 Mechanciallntegrity Test [Ø' 7/20/05 Sundry Number: .3> ç -;;J.. () / RBDMS BFl.JUl 282005 Location Clearance D BY ORDER OF THE COMMISSION ORIGINAL Date: ~/oS SUBMIT IN DUPLICATE { \ (' TREE = WELLtlEAD = ~C.TUA. TOR = KB. 8..EV = BF. 8..EV = KOP= Max Angle = l:etum M) = l:etum TVD = 5-1/8" FMC FMC AXELSON 74.0' NA 140ä 15-112" X4-1/2" XO H 52 @ 3000' 11495' 8800' SS 12-06A 25' \ I SAFETY NOTES: **"WAIVEREDWELL (02l22103)***TBG X IA COMM; LEAK@ GLM #4, GLV #4 COULOO'T BE PULLs) OS/27/95 OR 01/03199. 4-1/2" & 3-112" CHROME TBG. T' CHROM E L f\R FROM 11043' TO SHOE. Minimum ID = 2.750" @ 11208' 3-112" Parker SWN Nipple L 2192' H4-1/2" CAtv'CO BAL-O SSSVN,ID = 3.812" GAS LIFT MANDRELS ~ ST MD ND ŒV TYPE VLV LA TOi PORT DATE 1 3898 3384 46 TGPDX RK 2 6903 5434 45 TGPDX RK 3 9381 7200 43 TGPDX RK 4 1 0084 7720 40 FM-IO RK 5 1 0741 8228 36 FM-IO RK 6 11085 8516 31 FM-IO RKP 9571' H4-1/2" X 3-1/2" TBG XO,ID = 2.992" I ~. (i) 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2899' ~ 4-1/2"TBG, 12.6#, 13-CR, .0152 bpf,lD =3.958" H I BKR C-2 llEBACK SLEEV E, ID = 7.50" H 19-5/8" X 7" BKRH A<R, ID =6.181" 1-1 19-5/8" X 7" BKR HYFLO HGR, ID = 6.181" 1-1 9569' " ~ 9664' 9672' 9676' l ~ J f I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9832' 9-5/8" CSG MILLOUT WINOOW 9822' - 9892' (SECTION MILL) 17" LNR, 26#, 13-CR-80, .0383 bpf, D = 6.276" 1-1 11755' 11106' 1- 3-1/2" OTIS X NIP, ID = 2.813" I 11162' 1-i7" X 3-1/2" OllS MHR PKR, ID = 3.875" I I 11185' 1-13-1/2" OllS X NP, ID = 2.813" I 11208' 1-13-1/2" PARKERSWN NIP, D =2.750" 17" LNRXO FROM L-80 TO 13-CR-80 1-1 11043' I I 3-112" lEG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" 1-1 11220' 11221' 1-13-1/2"WLEG,ID=2.992" I 11229' 1-1 ELMD TT LOGGffi 07/11/92 ÆRFORA 1l0N SUMMA RY REF LOG: BHCS ON 06/25/1992 ANGLE AT TOP PERF: 29 @ 11329' Note: Refer to Production œ for historical perf data SIZE SFT NTffiVAL Opn/Sqz DATE 2-1/8" 6 11329-11341 0 10/14/93 2-1/8" 6 11341-11353 0 10/14/93 2-1/2" 4 11440-11460 0 10/22/97 2-5/8" 4 11458 - 11478 0 07/11/92 2-1/8" 4 11458-11478 0 08/10/92 2-1/2" 4 11480-11510 0 07/16/94 2-1/2" 4 11523-11570/ 0 07/16/94 11303' 1-i7" MARKERJT. (21') 11708' I-IPBTD I DATE 04/13/81 06/30/92 12/12/00 02/27/01 03/06/02 02/22/03 REV BY COMMENTS ORlGNAL COMA..ETlON RIG SIDETRACK SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL CH/TP CORRECllONS JMPiKK WA IVER SA FETY NOTE DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 12-06A ÆRMlT No: 1920540 API No: 50-029-20401-01 SEC 18, T10N, R15E, 579' NSL & 19' WEL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~ Commissioner ~,~ ~0~ Tom Maunder, ~ P. I. Supervisor "V" ~:~'~,~.,Ib \ FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: May 7, 2001 Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7, 2001: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with I failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summa.w: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS AlaSKa Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 Wall Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE , 12-01 1790230 ,. 12-02 1790320 ~2-03 17'90410 160 150~ 150 e P ' OIL 12-04A 1811870. '160 '15'0 150 e' P OiL 12-05 1790550 ~06~'::~!"'?::?~'1920540 ' 160 150 150 P P ..... OIL 12-07A 1811750 160 150 140 e p ' OIL 12'08B 1811670 160 15'0 140 ' P P ' OIL 12-09 1800930 160 150 125 P P OIL 12-10A 1920890 160 150 150 P P OIL 12-11 1810730i i2-i2 1810830 160 150 90 P 4 OIL 12-13B 1960170 160 ' 150 "150 P P OIL "i~-14A 1981460! 160 150 150 P P OIL ~ , , 12-15 1830320 160 150 150 P P OIL 12-16A 1931480 ' 160 150 15'0 P P OIL 12-17 1830040 160 " 150 150 P P OIL 12-18 1822060 160 150 150 P P 0IL 12-19 1821980 12-20 1821910 'i2-21 1840480 ' ,, 12-22 ' 1840600 160i 150'" 125 P e OIL 12-23 1840580 ,. . 12-25 1831660 12-26 1840140 160 150 '125 P ' e 'OIL 12-27A 1990390 12-28A 1990330 160 150 170 P P OIL , 12-29 1840320 ,- , , ., , 12-30 1881420 12-31 1890010 12-32 1'890'110 160 i50 150 e P 12-33 1890100 12-34 'i941370 'i60 15'0 '150' P' P ' O~L 12-35 '1'9~13001 16'0 " 150 100 ~2-36 1951580i 160 150 150 P 'P ' OIL RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p4~C~S II ] Number Wells: i Permit Number 21 Remarks: Separ Set PSI PSI Components: L/P Test Trip Code 42 Failures: net t "TestI Test'I ' Date CodeI Code] Passed 1 Failure Rate: Oil, WAG, GIN J, I I GAS or CYCLE 2.38% r-'! 90 Day Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS THE MATERIAI~ UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000. E M T-~ H ATE R IA L UN IS M ARK C:LORIXMFILM.DOC E W D E E R R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate__ Plugging __ Perforate _X , Pull tubing --, Alter casing __ Repair well __ Other__ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Devetopment_X 73' RKB 3. Address: Exploratory 7. Unit or Property: P.O. Box t00360 Stratagrapic Anchorage, AK 99510-0360 Service Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 579'N & 18'W of SE cr, Sec 18, T10N, R15E, UM. 12-06A At top of productive interval: 9. Permit number/approval number: 3924' SNL, 4312' WEL, Sec 16, T10N, R15E, UM. 92-54 At effective depth: 10. APl number: 50-029-20401-01 At total depth: 11 t. Field/Pool: 4025' SNL, 4212' WEL, Sec 16, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11775 feet Plugs (measured) Tagged Fill at 10499' MD (10/22/97). true vertical 9125 feet Effective Depth: measured 10499 feet Junk (measured) true vertical 8039 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 73' 20" 400 Sx AS II 73' 73' Surface 2826' 13-3/8" 2500 Sx PF 11 2899' 2714' Production 9759' 9-5/8" 1578 Sx Class G 9832' 7530' Liner 2048' 7" 340 S× Class G 11712' 9069' Perforation Depth measured 11329- 11353'; 11440-11478'; 11480- 11510'; 11523- 11570'0RIGINAL true vertical 8728 - 8749'; 8825 - 8860'; 8862 - 8888'; 8900 - 8941' · . , Tubing (size, grade, and measured depth) 5-1/'Z', 17#, L-80, Tbg @ 25' MD; 4-1/2", 12.6#, 13CR, Tbg @ 9569' MD; and · 3-1t2", 9.2#, 13CR, Tbg @ 11221' MD. Packers and SSSV (type and measured depth) Otis MHR Packer @ 1 t 162' MD; Camco Bal-O SSSV @ 2t 92' MD. 13. Stimulation or cement squeeze summary .. ~. . Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 416 2093 2592 317 Subsequent to operation 4t 1 2000 2577 337 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ ,~ Daily Report of Well Operations_X <~_ ~" / '.- Oil _X Gas m Suspended 1 ?. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~,~ ~1. ~ Title: Engineering Supervisor Date ~UEI~IlT tN DUPEI{~ATE PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 10/22/97: MIRU & PT equipment. Added Perforations: Reperforations: Rill w/perforating guns & shot 20' of perforations as follows: Ref. Log: BHCS 6/25/92. 11440- 11458' MD (Z2) 11458- 11460' MD (Z2) Ref. Log: BHCS 6/25/92. Used 2-1/2" carriers & shot the perfs at 4 spf at 180 degree phasing at balanced pressure. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid well test. STATE OF ALASKA ALASKA AND GAS CONSERVATION CO, ,IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 579' N & 18' W of SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-6A 9. Permit number/approval number 3924' SNL, 4312' WEL, Sec. 16, T10N, R15E, UM At effective depth At total depth 4025' SNL, 4212' WEL, sec. 16, T10N, R15E, UM 92-54 10. APl number 50 - 029-20401-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11775 feet 9125 feet Plugs(measured) Fill @ 11622' MD (7/16/94) Effective depth: measured 11622 feet true vertical 8988 feet Junk(measured) Casing Length Size Cemented Conductor 73' 20" 400 sx AS II Sudace 2826' 13-3/8" 2500 sx PF II Production 9759' 9-5/8" 1578 sx CIG Liner 2048' 7" 340 sx CIG Measured depth True verticaldepth 73' 73' 2899' 2714' 9832' 7530' 9664-11712' 9069' Perforation depth: measured 11329-11353'; 11458-11478'; 11480-11510'; 11523-11570' true vertical 8728-8749'; 8842-8860'; 8862-8888'; 8900-8941' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 25' MD; 4-1/2", 12.6#, 13 CR, Tbg @ 9569' MD; 3-1/2", 9.2#, 13 CR, Tbg @ 11221' MD Packers and SSSV (type and measured depth) 7" Otis MHR Packer @ 11162' MD; 4-1/2" Camco Bal-O @ 2192' MD 13. Stimulation or cement squeeze summary R ~' ~ ~ i V' J~ D Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation .Representative Daily Average production or Injection Data ~-llCO'Or;ue OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 642 1457 2457 -- Tubing Pressure 305 Subsequent to operation 812 1411 3456 277 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si-ned //~/~ 1. ^~ ~ Title Form 10-404 Re¢~6/15/88 1198/13 CC: KZ, JWP Engineering Supervisor Date SUBMIT IN DUPLIGATF~ 12-06A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/1 5/94: RIH w/CT & jetted a fill cleanout from 11481' to 11630' MD. 7/1 6~94 - 7/1 7/94: MIRU & PT equipment. RIH & tagged PBTD at 11622' MD. 77' of add perforations as follows: Added perforations: 11480 - 11510' MD (Z4) 11523 - 11570' MD (Z4) Ref. Log: BHCS RIH w/perforating guns & shot 6/25/92. Used 2-1/2" carriers, & shot 4 spf, at 180 degree phasing, at underbalanced pressures. POOH w/perf guns; noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. $00 W. International Airport Road Anchorage, AK 99E;18-1199 ATTN: Sherrie NO. 8832 Company: Alaska Oil & Gas Cons Comn , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 8/3/~4 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar ~..I~'T/12-6A . ._ ' PERF RECORD(7-17-94) ...... i 1 ,,,.--D~. 9-12 -7 '7 -- O '7 INJECTION PROFILE (7.-.15-94) 1 1 ...~ -D~. 17-6 ~'C~ -'-I '~ ~- INJECTION PROFILE*STATIC SURVEY (7-19-94) 1 1 ~.S. 7-30 ,,~-~.- ~ PRODUCTION PROFILE (7-13-94) 1 1 /'"'~5'33 "-~/'~~ "' TDT-P BoI~AX (7.-17.-.94) 1 1 ~ ~.'i8-29A' ~ ~ .-o ,./O ....... PRc~DuCT!ON PROFILE (1-14-94) 1 1 D.S. 16-25 ~ - PRODUCTION PROFILE (7-16194) 1 1 ,,, .i'"".' SI Pie urn one copy of this transmittal to Sherrle at the above address. Thank you. DATE: C~e<:~uest ~ W. International Ai~ Road Anchorage, Al( 99618-1199 ATTN: Sherrie NO. 8911 Company: Alaska Oil & Gas Cons Oomm , Mtn: Lam/Grant I 3001 Porcupine Drive Anchorage, AK 99501 9/6/94 Fielc~ Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar '~ ~-'"~' D.S. 18-11 . BRIDGE PLUG RECORD (8-14-94) 1 J 1 ~{'~1 D.S. 16-03 INJEO SURVEY (8-13-94) 1 1 ~'~_~._~ ~'5 C. D.S. 16-01 INJEO SURVEY (8-13-94) 1 1 ~'¥~ :~ ! - D.S. 12-28 PERF RECORD (8-10-94) 1 1 ~,2 -.~"~ _D.S. 12-10A iPROD PROFILE (8-13-94) 1 1 -.9'~ -~ D.S. 12-06A 'PROD LOG (8-12-94) 1 1 '?~'-Vi D.S. 12-3 PROD PROFILE (8-13-94) 1 . 1 ~"'~' ~,~ 'D.S. 12-1 PERF RECORD (8-10-94) 1 1 · ,t - ~t¥ D.S. 6-19 PROD PROFILE (8-12-94) 1 1 :2 '?- ?~ D.S. 01-14 POGLM SETTING RECORD (8-11-94) 1 1 ~'~-?'? D.S. 01-14 TUBING PUNCHER RECORD (8-11-94) 1 1 ?~ ~ {~ __D.S. 01-03 POGLM SETTING RECORD (8-14-94) 1 1 ,, SIGN ~-~-- . DATE: - - %/ £CEIVEfl Please sign ~d re~m one copy of ~io tmn~flal to Shale ~ ~e a~ve addre~. ~k you. _ ~ ~ ~ _ =~ka Oil & ~as Cons. Ce · PERMIT DATA 92-054 BHCS/GR 92-054 DLL/GR 92-054 LEAK 92-054 PERF 92-054 PERF 92-054 PFC/GR 92-054 PROD 92-054 PROD 92-054 407 92-054 DAILY WELL ©P 92-054 SURVEY 92-054 SURVEY 92-054 SURVEY AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 92-054 5317 L 11290-11709 L 11290-11732 L 5800-7010 L 11050-11600 L 11200-11457 L 11100-11675 L 1920-11477 L 2100-11644 R COMP DATE: 07/17/92 R 06/02/92-06/30/92 R 0-11687, SS DIRECTIONAL a 9822-11345, MWD R 9822-11687, EMSS T 11290-11776, OH-BCS/DLL Page: 1 Date' 06/13/94 RUN DATE_RECVD 1 07/13/92 1 07/13/92 I 10/05/92 1 12/30/92 1 12/15/93 1 08/10/92 1 04/27/94 1 10/05/92 09/03/92 09/03/92 09/03/92 08/03/92 08/03/92 1 07/13/92 Are dry ditch samples required? yes ~/And received? yes no Was the well cored? yes .~__ . Analysis & description received~ Are well tests required. Received. yes no · Well is in compliance ~ Initial COMMENTS yes no ARCO Alaska, Inc. Date: Apr 14, 1994 P.O. Box 100360, .. borage, AK Transmittal #: 94034 99510.d~ ~' Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location- John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Number Well Log Date i Tool Type 01-09A 01-1 01-33 03-01 o3-o (M-D-Y)! 04-02-94 i~' Perf Record 03-25-94 i TDT-P 03-28-94 i,/' TDT-P 03-27-94 iv- Perf Record 03-22-94 J-' Leak Detection 03-22-94 i,.' Bridge Plug 03-18-94 .k/Leak Detection i/ Bridge Plug i¢' Bridge Plug iv/ TDT-P S:~-~ ?...! 03-19 · ~ 03-29 ...'%.03-29 03-29-94 ¢/ CNTG 03-10-94 i ¢' USIT 03-13~94 iv' USIT 03-27-94 ~l.¢qT-i 03-31 03-27-94 !/04-43 03-29-94 ~q~tS!~ 04-43 i ~.04-43 Ic~,~. ~ Oi 04-44 i¢- USIT Cement Run, i,/ Perf Record Scale , 5II 7 511 1,5" 1 5" 1 2" 1 5" 1 5" 1 5" 1 5" 511 Contractor Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 1 511 04-45 i 03-29-94 1, 5" Sch 05-08 i 03-14-94 1-/ Prod Profile 1, 5" Sch 06-19 03-18-94 , Sch 11 511 511 Sch Sch Sch 07-08 ..... 04-03-94 !-, Perf Record 07-23_ 03-21-94 .J'/ Bridge Plug , 09-01 03-30-94 i,,. Prod Profile 09-02 03-17-94 i ./ Prod Profile 03-29-94 i/ Prod Log 04-01-94 i," Perf Record 03-16-94 i/ Prod Log 03-22-94 I / Perf Record 03-16-94 ! ¢' Patch setting 03-29-94 i '/ Perf Record 03-18-94t., Prod Profile 1, 1"&5" 1 511 1, 5" Sch 1, 1"&5" Sch Sch It 511 Sch 1, 5" Sch 1, 5" Sch Sch Sch 70-5c~ 09-03 '/~-,-to! 09-19 ~%-Z%.' 09-27 ~- (¢0i 11-04 ;[o~q i, 11-17 5--ZO~ 11-24A I7..-5~ 12-06A ~2.-(:::FI ! 13-20 03-15-94 t," Leak Detection 03-28-94 i -- CNL 03-19-94 i ~ Prod Profile 03-15-94 i¢' Leak Detection 03-28-94 i,/Patch Setting 03-21-94 !/ Bridge Plug 03-1 7-94 iv~ CNL 03-15-94 'i¢ Perf Record 03-14-94 i¢" Leak Detection 03-14-94 iv- Perf Record 03-20-94 i,,~ TDT-P 511 1, 1"&5" 511 1, 1 "&5" 1,5" Sch Sch Sch Sch Sch Sch Sch Sch 1,5" : 1.5" 1, 2"&5" Sch : Sch "~-'5~. i 14-03 ~?--~'f i '14-23 !//14-28 3L-~Z.~ 14-28 ~ , ~%14-28 ~5-1q~ 14:35 ~Z-t 5t~ 16-04A I~-~q~ 16-18 ~z-~2 i 16~28 ~-7~ ~8-o8 1,5" Sch Number of Records: 38 ARCO Alaska, Inc. I$ a Subsidiary of AtlanflcRIchfleldCompany ARCO Alaska~ Inc. P. OJ~x 100360 Anchorage, Alaska 99510 DATE: 12-1-93 REFERENCE: ARCO CASED HOLE FINALS ~-33 10-16-93 _ tL_2-1o 10-z 93 ~2-17 10-16-93 3.9 22 10-22-93 25 10-15-93 10-1893 q ~__ff~o-.~ 10-25-93 ~ 1~~3 1~1~93 ~S_~ ~93 ~~ ~2[~3 ~0~0 ~13 1~1~93 ~~~19 1~1~93 ~~~ 1~21~3 7~11 1~93 7~13 1~93 1~17~ 2-1~ 1~1~3 12-1~ 1~1~3 ~ ~ 12-1~ 1~1~93 ~ 12-~ 1~1~93 Prod Profile Run Peff Record 3~o-~qq Run Prod Profllel~m I~'m~[ Pe~"~~tgRun Dual B~t T~P ~ ~j ~ofllel~m USIT CCm,a~, Peri R~ InJ Profile 5a ~ tT~me I I&~>/6~- USIT (~-rost~ 3 Color PeffR~ It~b ~B~57 ~Peff R~o~ ~0- lo~o Collar ( ~ ~ C~ ~cker) a~ ~ ~z5 ~P ~t I~ ~ ~-l~ Completion ~i 00 -~ Plesse sign and return RECEIVED BY Have A Nice Day! receipt of data. Sonya Wallace ATO-1529 APPROVED Trans# 93144 # CENTRAL FILES # CttEVRON #BIX # STATE OF ALASKA 1, ~' ~:550"c~qq~e Sch 1, ~' Sch 1, l~'%~tt~l°W/5 Sch 1, ~' Sch 1, [~'q0~-~z~ Sch 1, 2"&i~' 0-Il 0o0 Sch 1,1~'1o~0o-~0535 Sch 1, 2"&5"qla~- 9q ~ZSch 1, Y'~' O- ~0 ~h 1, ~' Atlas 1, ~'~o ~q~0 ~h 1,~' ~-0~ Sch 1, W' ~h 1, ~' ~h 1, ~'~00 ~g0 ~h 1, W' ~h 1, W' ~h 1, 1"~' o-qo5E ~h 1, ~' ~h 1, ~' ~h 1, ~' ~50o ~1 oooo ~h 1, ~' ~h 1, W' ~h 1, W' ~h ~, W,e~~o At~s 1, W' ~tlas 1, 1"~'~0-1o7~ ~h 1, W' ~h 1, W' ~h * The correct Al'I# for 9-7 is 50-029-20223-00. STATE OF ALASKA ALASKA !_ AND GAS CONSERVATION C¢--~/IISSION REPORT 'vF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well , Perforate X · Other 6. Datum of elevation(DF or KB) 73' RKB 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 579'N & 18' Wof SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 3924' SNL, 4312' WEL, Sec. 16, T10N, R15E, UM At effective depth At total depth 4025' SNL, 4212' WEL, Sec. 16, T10N, R15E, UM 5. Type of Well Development Exploratory 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-6A 9. Permit number/approval number 92-54 10. APl number 50 - 029-20401-01 11. Field/Pool Prudhoe Bay Oil Pool Stratigraphic Service 12. Present well condition summary Total depth: measured true vertical 11775 feet 9125 feet Plugs(measured) Fill @ 11327' MD (10/20/93) Effective depth' measured true vertical 11327 feet 8726 feet Junk(measured) Casing Length Conductor 73' Sudace 2826' Production 9759' Liner 2048' Perforation depth: Size Cemented Measured depth True vertical depth 20" 400 SX AS II 73' 73' 13-3/8" 2500 sx PF II 2899' 2714' 9-5/8" 1578 sx CIG ~- (" ~[V 9832' 7530' 7" 340 sx CIG R L ~" ~"-- ~i"O 9664-11712' 9069' measured 11329-11353'; 11458-11478' ~,~,S~,~ (Jii & Gas Cons. C0mm'tss[0n Anchorage true vertical 8728-8749'; 8842-8860' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 25' MD; 4-1/2", 12.6~, 13-Cr, Tbg @ 9569' MD; 3-1/2", 9.2#, 13-Cr, Tbg @ 11221' MD Packers and SSSV (type and measured depth) 7" Otis "MHR" Packer @ 11162' MD; 4-1/2" Camco BaI-O @ 2192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 707 1646 2198 Tubing Pressure 304 Subsequent to operation 1076 2971 2062 -- 283 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'' Form 10-404 Rev 06/15/88 1072/6 KRF cc: SW, JWP Title Engineering Supervisor Date / ~'"/"~/~ ~ SUBMIT IN DUPLICATE 12-06A DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF SAG RIVER 10/14/93: RIH w/perforation gun & tagged bottom fill at 11460' MD, then PUH & shot Add Perforations at: 11329 - 11353' MD (Sag) Ref. Log: BHCS 6/25/92. POOH w/perforating gun. Rigged down. 10/15/93: MIRU & PT equipment. Loaded wellbore backside w/266 bbls Crude while RIH w/CT to PBTD. Pumped gelled sand slurry, to place a sand plug over the lower set of open perforations located at: 11458 - 11478' MD (Z4) Ref. Log: BHCS 6/25/92. Made a final top of sand plug tag at 11362' MD. POOH w/CT. Rigged down. 10/16/93: RIH & tagged top of sand plug at 11380' MD. 10/18/93: MIRU & PT equipment to 10700 psi. Pumped a Datafrac & Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforation interval located above the sand plug (listed above). Pumped 106 bbls 20# Datafrac Pre Pad @ 35 bpm, followed by Shutdown for pump repairs. Resumed pumping 140 bbls 20# Pre Pad @ 35 bpm, followed by Shutdown. ISIP @ 1340. Resumed Datafrac pumping 187 bbls 40# Crosslinked Pad @ 35 bpm, followed by 71 bbls 40# Crosslinked Pad @ 5 bpm, followed by 158 bbls 40# Crosslinked Pad @ 35 bpm, followed by 160 bbls 20# Gelled Flush @ 35 bpm, followed by Shutdown. ISIP @ 1880. Resumed pumping Fracture Treatment of 350 bbls 40# Crosslinked Pad @ 35 bpm, followed by 505 bbls Crosslinked Slurry w/proppant stages @ 1 - 10 ppg, followed by 83 bbls 20# Gelled Flush, followed by Shutdown. Placed a total of 77,911 lbs of proppant into the formation. Rigged down. 10/19/93: RIH w/CT & jetted a proppant fill cleanout to 11490' MD, to uncover the open perforations (above). 10/20/93: RIH & tagged bottom proppant fill at 11327' MD. Returned the well to production w/gaslift & obtained a valid welltest. ARCO .~l~skn; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 ARCO CASED HOr~. FINALS , 1.5ST~9/~9.29.92 1-29~-/°~' 12-8-91 2-11 ?~-~ 10-26-92 2-22~2-~/~/ 10-26-92 ~- ~ ~/ 4-14~ 10-29-92 7-11/~_- g~ 8-14-92 7-13 ?~-2o 7-31-92 ~-~-~/ ** 12-6A 8-10-92 ~/-~ 12-22 8-10-92 14-41}~2-~ 10-25-92 Perf Record TMD CCL (Peri) CCL (Peri) s /al CC Perf Record TMD (Borax) Perf Record Perf Record GR/CCL (Perf Depth) Run 1, 5" R-n 1, 5" R-n 1, 5" R~m 1, 5" R-n 1, 5" R-n 1, 5" Run 1, 5" R~m 1, 5" R-n 1, 5" Run 1, 5" HLS HLS Atlas Atlas Arias HLS HLS HLS HLS Sch Sonya Wallace ATO-1529 Please sign and return the attached copy as receipt of data. RECEIVED BY ~-~~ Have A Nice Day! RECEIVED DEC 0 1992 Trans# 9226~-' -ENT lJaskaO!l& Gas Cons. Commission # C RAL FILF-,~chorage # CHEVRON D&M # EXTENSION EXPLORATION # EXXON ' MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct APl# for 1-5ST is 50-029-20076-00. The correct APl# for 12-6A is 50-029-20401-01. STATE OF ALASKA "~ ALASKA-'-'x, AND GAS CONSERVATION C¢'-'--'/IISSION REPORT SUNDRY WELL OPErlATIONS0 I{ i I N A [ 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 579' N & 18' W of SE cr, Sec. 18, T10N, R15E, UM 6. Datum of elevation(DF or KB) 73' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12~6A At top of productive interval 3924' SNL, 4312' WEL, Sec. 16, T10N, R15E, UM At effective depth RECEIVED OCT 2 6 3992 At total depth ~_aS~ ~ji & Gas Cons. (;omrnissio~ 4025' SNL, 4212' WEL, Sec. 16, T10N, R15E, UM feet 9. Permit number/approval number 92~54 10. APl number 50 - 029-20401-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11775 feet 9125 feet Plugs(measured) Fill @ 11578' MD (9/13/92) Effective depth: measured 11578 feet true vertical 8948 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 73' 20" 400 sx AS II 73' 73' Surface 2826' 13-3/8" 2500 sx PF II 2899' 2714' Production 9759' 9-5/8" 1578 sx CIG 9832' 7530' Liner 2048' 7" 340 sx CIG 9664'-11712' 9069' Perforation depth: measured 11458-11478' true vertical 8842-8860' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 25' MD; 4-1/2", 12.68, 13-Cr, Tbg @ 9569' MD; 3-1/2", 9.2#, 13-Cr, Tbg @ 11221' MD Packers and SSSV (type and measured depth) 7" Otis "MHR" Packer @ 11162' MD; 4-1/2" Camco Bal-0 @ 2192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Pr0ductionorlniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 269 449 298 -- · 1301 J'~ 3843 2949 -- Tubing Pressure 327 273 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x. Gas ~.. Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 909/12 DTK CC: SW, JWP Title Sr. Area Operations Engineer SUBMIT IN DUPLICATE ..~ 12-06A DESCRIPTION OF WORK COMPLETED ROPE PERFORATIONS & FRACTURE TREATMENT OF ZONE 4 7/1 I/92: MIRU & PT equipment. RIH w/perforating gun & logged into position. Pumped Freshwater down the tubing & pressured up to 4500 psi w/nitrogen, to perform a ROPE (Really Overpressured Perforation Extension) Treatment, then shot the initial perforations at: 11458 - 11478' MD (Z4) Ref. Log: BHCS 6/25/92. 8/10/92: Reperforated: 11458 - 11478' MD (Z4) Ref. Log: BHCS 6/25/92. 9/1 I/92: MIRU & PT to 8800 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the perforations (listed above). Pumped: a) 251 bbls Pre Pad, @ 30 bpm, followed by b) Shutdown. ISIP @ 2100. Resumed pumping: c) d) e) 165 bbls 20# Gelled Flush, followed by f) Shutdown. 50 bbls 40# Crosslinked Pad @ 30 bpm, followed by 309 bbls Slurry w/proppant stages @ 1 - 10 ppg, followed by Placed a total of 60,300 lbs of proppant into the formation. Rigged down. 9/1 2/92: Performed a proppant fill cleanout to 11652' MD. 9/1 3/92: RIH & tagged bottom fill at 11578' MD. Placed well on production w/gaslift & obtained a valid welltest. RECEIVE,g OCT 6 199 Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-2-92 REFERENCE: __. ~'3 2-13_ ~z7 a-~ .... ARCO CASED HOT.E F1NA~ 9-1-92 Prod Prome ~m L 5" 9-6-92 Leak Detect (Flexsta]0 Run 1, 5" 9-6-92 ~ Detect (~ezstak) Run 1, 5" 8-21-92 Prod Profile Run 1, 5" 8-31-92 Leak Detect (Flexstak) Rim 1, 5" 8-21-92 Prod Profile Run 1, 5" 8-30-92 GR/Collnr Rml 1, 5" 9-7-92 PITS Run 1, 5" 8-24-92 Collar/Baker IBP Run 1, 5" 9-1-92 Prof Profile Run 1, 5" 9-1-92 Prod Profile Run 1, 5" 9-24-92 Perf Breakdown l~m 1, 5" Please sign and return th~ atta~ copy as receipt of data. c Sonya Wallace 199 APPROVED_ AT0-1529 ~as~a 0ii & Gas ¢0ns. ~0mm/~# 9221~ ' # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON_ # MOBIL # PHILLIPS PB WF.T.~'. FILES R&D # BPX # STATE OF ALAS~ C~mco C~_ mco Camco C~mco C~mco C~mco Camco ~co C~mco ~mco ~mco ~co ~mco ~mco ~mco ~mco ~mco * This is not a field print for 1-11. 0 "--'" STATE OF ALASKA '~' ~ I~ I~ ALASKA ,~L AND GAS CONSERVATION CO,v~MISSION ~ WELL COMPLETION OR RECOMP LETION REPORT AND LO t. Status of Well Classification of Service Well OIL [] GAS !-1 SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-54 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20401-01 4. Location of well at surface 9. Unit or Lease Name 579'NSL, 19' WEL, SEC. 18, TION, R15E ~ C._.~~~'~~ I. OC^TiO~ I Prudhoe Bay Unit 3924'SNL,AI Top Producing Inlerva14312, WEI~ SEC. 16, TION, R15E ~; ~"':::~:'(J~J ~ 'Y'~'~' I 10. Well Number t~ _~... I :11. Field and Pool Bay Field/Prudhoe Bay Pool 4025' SNL, 4212' WEL, SEC. 16, TION, R15E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designalion-~n-d Serial No. KBE ,, 74' I ADL 28331 12. Date Spudded 13. Date T.D. Reached i4. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 6/3/92 6/24/92 6/30/92] N/A feet MSL ] One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey ~>0. Depth where SSSV set ~1. Thickness of Permafrost 11755'MD/9108'TVD 11708'MD/9065'TVD YES E] NO []! 2193'feet MD J 1900'(Approx.) 22. Type Electric or Other Logs Run DLIGR/BCS 23. CASING, LINER AND CEMENTING SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Cond. Weld Surface 73' 30" 400 sx Arcticset II 13-3/8" 72# L-80 Surface 2899' 17-1/2" 2500 sx Pernafrost II 9-5/8" 47# L-80 Surface 9832' 12-1/4" 1578 sx Class "G" 7" 26# 13CR80 9664' 11712' 8-1/2" 340 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD) 5-1/2"X4-1/2"X 11221' 11162' 2-1/8" Gun Diameter 4 spf 3-1/2" MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11458'- 11478' 8846'-8860' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL 10300' Bridge Plug 9892' K/OPlug . 180 cuft Class "G"squeezed to 2500 psi 9908'-10140' 171 SX Class "G" Well freeze protected wi 150 BBL's Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/17/92 .. I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I iFIow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. ,Submit core chips. R'ECE:IVED $ E P - 3 1992 Alaska Oil & Gas Cons. 6ommis¢o~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure dala, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 11322' 8730' Shublik 11350' 8746' Top Sadlerochit 11440' 8826' Zone 3 11672' 9033' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. ~" ~ Title Drilling EngineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~, ~ C ~lV E D Item 28: If no cores taken, indicate "none". Form 10-407 S E P - 3 7992 Alaska 0il & Gas Cons. (;0rnrnissio~ Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 12-6A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20401 PERMIT: APPROVAL: ACCEPT: 06/02/92 04:06 SPUD: 06/12/92 08:06 RELEASE: 06/29/92 07:06 OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 06/02/92 (1) TD:ll911 PB: 0 PREP TO CIRC WELL MW: 8.5 Seawater MOVE RIG, RAISE DERRICK, SPOT RIG. SHIM & LEVEL. SPOT TANKS, RU TO CIRC ON TREE. RU FLOOR, PREP TO TAKE ON SW. 06/03/92 (2) TD:ll911 PB: 0 06/04/92 (3) TD: 11911 PB: 0 06/05/92 (4) TD: 11911 PB: 0 06/06/92 (5) TD: 11911 PB: 0 06/07/92 (6) TD:ll911 PB:10300 POH L/D 5-1/2" TBG MW: 8.5 Seawater TAKE ON SEAWATER, PULL BPV, CIRC OUT GAS/CRUDE, ND TREE, NU BOPE, TEST, 3-1/2" X 6" VBR'S FAIL, REPLACE, TEST OK, PULL HGR, TBG FREE, CBU, POH, L/D TBG. MU SECTION MILL/BHA #1 MW: 8.5 Seawater FINISH LD 5-1/2" TBG, TEST CSG TO 11200' (TOC) SET BRIDGE PLUG, RIH W/ 5" DP, TO 10300', CLEAR FLOOR, STRAP/CALIPER & PU SECTION MILL/BHA #1 RIH'W/SECTION MILL MW: 8.5 Seawater FINISH STRAP CALIPER & PU BHA #1, RIH W/SECTION MILL TO 10300', DISPLACE WELL BORE W/DRLG MUD, SPOT 15BBL PILL F/iO3OO'-IOiOO',BEGIN TO CUT SECTION, AFTER 4-6" COULD NOT MAKE HOLE, BREAK ROTARY CHANIN, 1 HR DOWNTIME TO REPAIR CHAIN, RESUME MILLING, NO PROGRESS, SHUTDOWN, PUMP PILL, POH W/SECTION MILL, CHG OUT MILL, RIH W "D" SECTION MILL. RIH W/ SECTION MILL MW: 8.5 Seawater CUT N'SLIP DRLG LINE, RIH W/BHA #2(TRISTATE "D" SECTION MILL) TO 10045', BEGIN ROTATE, NO SUCCESS, CIRC, SHUTDOWN & MOVE UP HOLE TO RESTART, SPOT CUTTERS @ 9928', 2 HRS TO GET CUTOUT, BEGIN MILLING, MAKE 4" NEXT HR, GOOD SHAVINGS, MAKE 8" OVER NEXT 3-1/2 HRS, QUIT MAKING HOLE, MILL QUIT, CIRC HOLE CLEAN, MIX & PUMP PILL, POH W/MILL PREPARE SPOT CMT PLUG MW: 8.5 Seawater GOT CUTOUT @ 9822', ATTEMPT TO MILL CSG F9822', VARY PUMP RATE FROM 50-103 SPM, VARY WEIGHT ON MILL, IN EFFORT TO GET MILL TO BITE WENT TO 27000# @ 40 RPM, TORQUE DECREASED TO 560 AMPS, MIX & PUMP SLUG, POH, RU BAKER RETREIVABLE PKR, RIH, SPOT PKR @ 9918', PRESSURE UP & TEST, POH W/PKR, RIH W/MULESHOE TO 10140', RU HALLIBURTON, 'PREPARE TO SPOT BALANCED PLUG FROM 10140'-9722' RECEIVED. WELL : DS 12-6A OPERATION: RIG : DOYON 16 PAGE: 2 06/08/92 (7) TD:ll911 PB:10300 06/09/92 (8) TD:ll911 PB:10300 06/10/92 (9) TD:ll911 PB: 9908 ATTEMPT MILLING @ 9822' MW: 8.5 Seawater FINISH TIH W TRISTATE SECTION MILL, LOCATE CUTOUT @ 9928' ATTEMPT TO MILL, NO GO, CBU, POH, RIH W/ SMITH MILLMASTER, DROP BELOW CUTOUT BRING PUMP UP 1000 PSI @ 44 SPM, BEGIN PICKUP, LOSE 150 PSI TO VERIFY CUTOUT @ 9928', BEGIN MILLING, NO GO, RIH TO 10035' CBU, MIX & PUMP PILL, POH & SPOT CUTTERS @ 9822', ATTEMPTING 3RD CUTOUT, (GOT CUTOUT @ 0600 HRS) MU SMITH MILLMASTER MW: 8.5 Seawater CIRC CSG VOL @ 106BPM, FINISH RU HALLIBURTON CMT SERV., PUMP 10 BBL H20, PUMP 30.5 BBL CLASS "G", B/O & LD PIN, REV CIRC, SQUEEZE CMT TO 3000 PSI, BLEED PRESSURE, CIRC, MIX & PUMP SLUG, PULL WEAR RING , TEST BOPE, INSTALL WEAR RING, PU KELLY, WASH/REAM TAG MED HARD CMT @ 9800'MD, MILL TO 9908', CMT HARD F/9868' TO 9908', CIRC, POH, B/O & L/D CMT MILL, PU MILLMASTER MILL 9-5.8" SECTION. MW: 9.4 RIH W/ STC MILLMASTER. MILL 9-5/8" CSG SECTION F/ 9822'-9864'. WBM 06/11/92 (10) TD:ll911 PB: 9908 06/12/92 (11) TD:ll911 PB: 9908 06/13/92 (12) TD:10139' ( 0) 06/14/92 (13) TD:10729' ( 590) PREPARE TO SET KICKOFF PLUG MW: 9.4 WBM MILL SECTION OF 9-5/8" CSG TO 9882', CIRC HOLE CLEAN, PUMP HI-VIS SWEEP, LARGE VOL OF METAL CUTTINGS ACROSS SHAKER ON FIRST CIRC. PUMP PILL, POH W/SECTION MILL, LD BHA & MILL, RIH W/5" DP, DRIFT EA STAND, BREAK CIRC ON EA ROW, WASH DOWN THRU OPEN HOLE SECTION F/9822'-9892', TAG UP SOLID @ 9892', REV CIRC, RU HALLIBURTON, BATCH MIX CMT, PREPARE TO SET KO PLUG. NOTE: EFC RAISED DUE TO DIFFICULTY IN CUTTING SECTION IN 9-5/8" CSG WHICH ADDED 2 DAYS TO THE WELL. CHANGE OVER MUD. MW: 9.4 WBM PUMP 16 BBLS WATER, 32 BBLS CMT, 4 BBLS WATER. DISP W/ MUD. POOH 12 STDS. SQZ CMT W/ 2500 PSI. POOH. TEST BOPE. RIH W/ BHA, BIT. TAG TOC @ 9567' DRLG CMT F/ 9567'-9832' DISP MILL FLUID W/ KCL MUD. DRLG W/MUD MOTOR MW: 9.5 VIS: 46 CLEAN PITS, TAKE ON NEW MUD IN PITS (KCL), CHG SHAKER SCREENS, ORIENT W/MWD, ESTABLISH KO, SLIDE W/MOTOR UNTIL OUT OF SECTION. F/9832' TO 9884', SLIDE & ROTATE W/STEERABLE DRLG SYSTEM F/9884' TO 10139' DRLG W/MUD MOTOR MW: 9.6 VIS: 74 SLIDE & ROTATE W/STEERABLE DRLG SYSTEM F/10139' TO 10729' RECEIVED Anc ' ora,9 WELL : DS 12-6A OPERATION: RIG : DOYON 16 PAGE: 3 06/15/92 (14) TD:ll020' ( 291) 06/16/92 (15) TD:11445' ( 425) 06/17/92 (16) TD:11445' ( 0) 06/18/92 (17) TD:11445' ( 0) 06/19/92 (18) TD:11445' ( 0) DRILLING MW: 9.6 VIS: 58 DRLG F/10729' TO 10852', CIRC HOLE VOL, DROPPED SINGLE SHOT · PUMP PILL, POH, HOLE CLEAN, RECOVERED SURVEY, LD MUD MOTOR, CHG OUT MWD, CHG BIT, M/U PACKED ASSEMB. RIH W/ BHA #2, FILL PIPE & BROKE CIRC @ 5000' & 9800', P/U KELLY, REAM 10802' TO 10852', DRLLED TO 11020' WORKING STUCK PIPE MW: 9.6 VIS: 61 DRILLED F/ 11020' TO 11445, STRING TORQUED UP, STALLED OUT, PICKED UP, PIPE STUCK, BIT ON BTM, CIRC POSSIBLE, DOWNHOLE MWD STILL WORKING, STUCK BELOW MWD, WORKED PIPE UP, PUMP 30 BBLS SFT PILL, SOAK COLLARS, WORKED PIPE UP, JARS STILL WORKING, PUMP PILL AROUND @ 1BBL/HR RIH W/FISHING ASSEMB. MW: 9.6 VIS: 61 WORKED PIPE· PUMPED ROUND SFT @ 1BBL/HR, NO MOVEMENT OFF BTM, MAKE BLIND BACK-OFF IN DP TO REMOVE KELLY, PIPE BACKED OFF @1800' (KOP)P/U ELEVATORS· P/U 2 JTS HWDP, SCREW BACK INTO DP @ 1800', RIH W/WL & STRING SHOT, FIRE SHOT @ CONNECTION BETWEEN NMDC'S ABOVE MWD, DID NOT BACK OFF, POH W/STRING SHOT, M/U NEW STRING SHOT & RIH, FIRE SHOT @ XO BENEATH JARS, PIPE BACKED OFF, P/U & UNSCREW FROM FISH, PULL STRING SHOT TO SURFACE, R/D W/L, CBU, OIL STAINED MUD & GAS PRESENT, STRUNG THRUOUT MUD COLUMN, POH, RECOVERED STRING DOWN TO & INCL. JARS, M/U FISHING ASSEMB, L/D HWDP, RIH W/FISHING ASSEMB. RIH W/FISHING ASSEMB. MW: 9.6 VIS: 55 RIH W/FISHING ASSEMB, BROKE & RETORQUED ALL CONNECTIONS, TAGGED FISH @ 11261', M/U SCREW IN SUB TO FISH, ESTABLISH CIRC THRU FISH, JARRED ON FISH, NO PIPE MOVEMENT ON BOTTOM, MWD STILL FUNCTIONING, R/U W/L, PUMP 20 BBLS SOFT PILL, & SPOT AROUND FISH, RAN FREEPOINT INDICATOR, PIPE STUCK @ TOP STABALIZER, POH W/FREEPOINT, RAN STRING SHOT CHRG, WORKED 7-1/4 LH TURNS ONTO STRING, FIRED SHOT @ X/O BELOW SIS,NO SURFACE INICATION OF BACK OFF, TORQUE DROPPED OFF, BACKED OFF & P/U PIPE· R/D W/L, POH, L/D 6 DC, LEFT SCREW IN SUB ON FISH, M/U NEW SIS, RIH W/FISHING ASSEMB. RIH W/CMTG STRING MW: 9.6 VIS: 58 RIH W/FISHING ASSEMB, TAG FISH @ 11259', M/U SCREW IN SUB TO FISH, TORQUED UP CONNECTION, JARRED ON FISH, FULL CIRC STILL POSSIBLE, NO PIPE MOVEMENT OFF BTM, R/U W/L, DP SWIVEL, & PUMP-IN SUB, PIPE STUCK @ TOP OF STABALIZER, RIH W/BACK OFF SHOT, FIRED SHOT @ XO, R/D W/L, POH, LD FISHING TOOLS, RECOVERED SIS FROM 2ND RUN, lST SIS STILL ON FISH, P/U 14 JTS 2'7/8" TBG, RIH W/CMT STRING. RECEIVED WELL : DS 12-6A OPERATION: RIG - DOYON 16 PAGE: 4 06/20/92 (19) TD:10809' ( 0) 06/21/92 (20) TD:10910' ( 101) 06/22/92 (21) TD:ll125' ( 215) 06/23/92 (22) TD:ll186' ( 61) 06/24/92 (23) TD:11426' ( 240) 06/25/92 (24) TD: 11755' ( 329) PREPARING TO TEST BOPE MW: 9.6 VIS: 51 ATTEMPTED TO BREAK CIRC IN CMT STRING, STRING PLUGGED, POH, WET TRIP, LD TBG, 10' OF DP PLUGGED W/SHALE & METAL CTGS, RIH W/3-1/2" DP STINGER, BREAK CIRC. EVERY 10 STD IN CSG, EVERY STND OPEN HOLE, TAG FISH @ 11259', CBU, PUMPED 14.5 BBLS ARCO PREFLUSH, 30 BBLS CMT SLURRY ( NEAT G), PULLED 16 STDS DP INTO CSG, CIRC W/ BACK PRESSURE FOR DOWN SQUEEZE ON CMT, NO CMT RTNS, POH, L/D 3-1/2" DP (PIPE CLEAN), SLIPPED & CUT DRLG LINE. ROTATING DOWN @ 10916' MW: 9.6 VIS: 50 PULLED WEAR BSHING, TESTED BOPE, RAN WEAR BSHING, P/U MUD MOTOR, RIH TO TOP HWDP, TIGHT SPOT ENCOUNTERED @ 10459', REAMED F/10459'-10783' TAGGED UP ON CMT @ 10783', ROTATED , DOWN & DRLD CMT F/10783' TO 10853', ALIGNED TOOL FACE, ATTEMPTED TO KICK-OFF PLUG, BEGAN SLIDING @ 10853', SLID TO 10876', NOT ABLE TO GET KICKED OFF, NO SHOULDER FORMING, ROTATED DWN TO 10916' DRLG @ 11125' MW: 9.6 VIS: 56 ROTATED DOWN F/10916' TO 10949', CMT FIRMED UP, ALIGNED TOOL FACE, KICKED OFF FROM CMT PLUG, SLID F/10949' TO 11002', ROTATED ONE SINGLE DOWN 11002' TO 11033' SLID ONE , SINGLE, 11033' TO 11063', ROTATED DOWN 11063' TO 11125' NOTE: EFC RAISED DUE TO STUCK PIPE. LEFT MWD IN HOLE ($300,000) AND CMT & SIDETRACK COST. REAMING MOTOR RUN MW: 9.6 VIS: 51 SLID 11125'-11156', ROTATED DOWN 11156'-11186', CIRC, POH, WET TRIP, L/D MWD & MUD MOTOR, CLEANED FLOOR, M/U NEW BIT RIH TO KO PT, RAN STABS THRU KO PT, LIGHT REAMED MOTOR RUN 10963'-11186' DRILL 8-1/2 HOLE MW: 9.7 VIS: 61 WASH & REAM F/10963'-11186', TIGHT SPOT @ 1113'-11138' WORK THRU TIGHT SPOT UNTIL CLEANED UP, DRILL 8-1/2" HOLE F/11186'-11356', BROKE REDUCTION GEAR CHAIN ON ROTARY TABLE, REPAIR & REPLACE, DRILL TO 11426', EST TOP OF SAD @ 11440', EST TD @ 11755'. POH FOR LOGS MW: 9.7 VIS: 53 DRILL 8-1/2" HOLE F/11426' TO 11691'' (EXCESSIVE TORQUE @ 11443') P/U WT 400K, PUMP SWEEP & ADD EP MUD LUBE, P/U WT. 340K, CONTINUE TO DRILL 8-1/2" HOLE TO 11755' TD, CIRC, KELLY UP, WASH & REAM F/11755' UP TO 9693', THRU SECTION MILL RUN, KELLY UP~ WASH & REAM F~ 11737' TO 11755', CBU, PUMP SWEE[, HOLE CLEAN, WELL STABLE, POH FOR LOGS. SEP - 5 !992 Anchorage WELL : DS 12-6A OPERATION: RIG : DOYON 16 PAGE: 5 06/26/92 (25) TD:11755' ( 0) 06/27/92 (26) TD:11755 PB: 0 06/28/92 (27) TD:11755 PB: 0 06/29/92 (28) TD:11755 PB: 0 RIH W/7" LINER MW: 9.7 VIS: 58 POH FOR LOGS, R/U SCHLUMBERGER, RIH W/LOGS, TAG BTM @ 11750', LOG OPEN HOLE W/ DL/GR/BCS, RIH W/8-1/2" BIT FOR WIPER TRIP, KELLY UP, WASH & REAM F/ 11680' TO 11755', CBU, PUMP SWEEP, HOLE CLEAN, DROP SURVEY TOOL, POH F/LINER, R/U CSG CREW, RIH W/7" CHROME LINER RIH. MW: 9.6 KC1 RIH W/ 7" LNR ON DP. TAG @ 11755'. CIRC. PUMP 74 BBLS CMT. BUMP PLUG W/ 3000 PSI. SET HGR, LNR TOP PKR. RELEASE F/ HGR. POOH. RIH W/ BIT, CSG SCRAPERS. RIH W/ TBG. MW: 8.5 Seawater RIH. TAG 7" LC @ 11708' REV CIRC. TEST LNR. REV CIRC. DISP W/ SEAWATER. POOH TO TOL. REV CIRC. POOH. L/D DP. R/U TORQUE TURN, OTIS. RIH W/ 4-1/2" X 3-1/2" 13 CR TBG. LADN TBG. MW: 8.5 Seawater RIH W/ 4-1/2" X 3-1/2" 13 CR TBG. M/U SSSV. RIH W/ TBG. M/U TBG HGR. DROP BALL TO SET PKR. LAND TBG. 06/30/92 (30) TD:11755 PB: 0 RIG RELEASED 19:00 MW: 8.5 Seawater PRESSURE UP ON TBG TO SET PKR, N/D BOPE, N/U TREE, ATTEMPT TO TEST TREE, FLOWLINE VALVE WILL NOT TEST, DSM ATTEMPT TO REPAIR VALVE, WILL NOT TEST, DSM WILL CHG OUT VALVE AFTER RIG RELEASE, DISPLACE ANNULUS W/150 BBL'S DIESEL, SET BPV SECURE TREE, RELEASE RIG @ 19:00. SIGNATURE: (drilling superintendent) DATE: RECEIVED Gas Cons, Gommissto~ gnchora9o PRUDHOE BAY DRILLING DS 12-06 A P ,5 1992 Gas Cot~s. Commissior, Anchorage, GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY DS 12-06A WELL NAME PRUDHOE BAY LOCATION AL692D24 MWD 06/29/92 JOB NUMBER BOB MAGOS TYPE SURVEY DIRECTIONAL SUPERVISOR DATE NAME TITLE SIGNATURE 0.0 FT 11687.0 FT DEPTH INTERVAL FROM TO 06/01/92 06/22/92 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING, Client · Field ..... : Well ...... : Section at: Engineer..: PRUDHOE BAY DRILLING PRUDHOE BAY DS12-06A S,42.33,E ROBERT MAGOS INC. 06/29/92 S MEAS INCLN C DEPTH ANGLE 7 0 0.00 7 100 0.00 7 200 0.00 7 300 0.00 7 400 0.00 VERTICAL-DEPTHS BKB SUB-SEA 0.0 -74.0 100.0 26.0 200.0 126.0 300.0 226.0 400.0 326.0 7 500 0.00 500.0 426.0 7 600 0.00 600.0 526.0 7 700 0.00 700.0 626.0 7 800 1.25 800.0 726.0 7 900 3.50 899.9 825.9 7 1000 4.25 999.7 925.7 7 1100 6.75 1099.2 1025.2 7 1200 8.28 1198.3 1124.3 7 1300 9.28 1297.2 1223.2 7 1400 10.00 1395.8 1321.8 7 1500 9.75 1494.3 1420.3 7 16.00 10.00 1592.8 1518.8 7 1700 10.75 1691.2 1617.2 7 1800 14.00 1788.8 1714.8 7 1900 17.75 1885.0 1811.0 7 2000 21.00 1979.3 1905.3 ^Survey Codes: 7/GYRO (GLDD (c) 92 DS1206A $1.30 10:02 AM 2) SECTION DISTNCE 0.0 0.0 0.0 0.0 0.0 RECORD OF SURVEY DIRECTION BEARING N 0.00 E N 0.00 E N 0.00 E N 0.00 E N 0.00 E 0.0 N 0.00 E 0.0 N 0.00 E 0.0 N 0.00 E 0.5 N 77.50 E 2.9 N 83.00 E 6.7 11.1 14.9 17.8 21.0 Computation...: Survey Date...: KB Elevation..: Reference · Magnetic Dcln.: MINIMUM CURVATURE 06/22/92 74.00 ft 4J0164 30.20 E 24.9 28.6 32.1 36.9 43.2 49.9 RELATIVE-COORDINATES FROM-WELL-HEAD 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.0N 0.0E 0.2N 1.1E 0.8N 5.2E N 81.00 E 1.8 N 11.8 E N 72.00 E 4.2 N 21.1 E N 59.00 E 9.7 N 32.9 E N 58.00 E 17.7 N 45.9 E N 59.50 E 26.4 N 60.2 E N 62.00 E N 58.00 E N 60.00 E N 61.00 E N 61.00 E 34.8 N 75.1 E 43.3 N 90.0 E 52.6 N 105.4 E 63.1 N 124.1 E 76.4 N 148.0 E N 58.00 E 93.3 N 176.5 E CLOSURE DL DISTNCE BEARING / 100 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 1.1 N 77.50 E 1.25 5.2 N 80.71 E 2.26 12.0 N 81.38 E 0.76 21.5 N 78.76 E 2.64 34.3 N 73.53 E 2.28 49.2 N 68.90 E 1.01 65.7 N 66.34 E 0.76 82.8 N 65.18 E 0.50 99.9 N 64.29 E 0.73 117.8 N 63.48 E 0.83 139.2 N 63.04 E 3.26 166.6 N 62.70 E 3.75 199.7 N 62.15 E 3.40 ! ! ' 1 ! ! ! I I I ! ! I I 1 1 ! ....1 ...... 1 .... 1 DS12-06A S MEAS INCLN C DEPTH ANGLE 7 2100 24.00 7 2200 27.00 7 2300 29.75 7 2400 33.00 7 2500 35.50 VERTICAL-DEPTHS BKB SUB-SEA 2071.7 1997.7 2162.0 2088.0 2249.9 2175.9 2335.3 2261.3 2418.0 2344.0 7 2600 38.75 7 2700 41.25 7 2800 45.25 7 2900 50.25 7 3000 51.05 SECTION DISTNCE 7 3100 50.50 7 3200 47.50 7 3300 47.25 7 3400 47.25 7 3500 47.25 RECORD OF SURVEY 7 3600 46.75 7 3700 46.50 7 3800 46.25 7 3900 45.50 7 4000 45.25 DIRECTION BEARING 7 4100 45.00 7 4200 46.25 7 4300 48.00 7 4400 51.00 7 4500 49.25 RELATIVE-COORDINATES FROM-WELL-HEAD 7 4600 49.25 7 4700 48.50 7 4800 49.25 7 4900 48.50 7 5000 48.25 57.3 N 59.50 E 113.1 N 209.3 E 67.1 N 62.00 E 134.1 N 246.8 E 77.2 N 58.00 E 157.9 N 287.9 E 87.4 N 60.00 E 184.7 N 332.6 E 99.9 N 61.00 E 212.4 N 381.6 E 2497.7 2423.7 113.9 2574.3 2500.3 127.0 2647.1 2573.1 139.9 2714.3 2640.3 154.4 2777.7 2703.7 170.9 2841.0 2767.0 189.5 2906.6 2832.6 208.8 2974.3 2900.3 228.8 3042.2 2968.2 250.7 3110.1 3036.1 273.2 3178.3 3104.3 295.0 3246.9 3172.9 316.6 3315.9 3241.9 338.2 3385.6 3311.6 360.2 3455.8 3381.8 382.5 3526.4 3452.4 404.8 3596.3 3522.3 429.7 3664.4 3590.4 460.5 3729.3 3655.3 496.0 3793.4 3719.4 535.8 3858.7 3784.7 578.5 3924.5 3850.5 620.5 3990.3 3916.3 662.4 4056.0 3982.0 704.9 4122.5 4048.5 747.0 N 61.00 E 241.6 N 434.3 E N 58.00 E 274.3 N 489.7 E N 59.00 E 310.0 N 548.1 E N 59.00 E 348.2 N 611.5 E N 61.00 E 386.8 N 678.5 E N 62.00 E 423.8 N 746.6 E N 63.00 E 458.6 N 813.5 E N 64.00 E 491.5 N 879.4 E N 66.00 E 522.5 N 945.9 E N 65.00 E 552.9 N 1012.7 E N 65.00 E 583.9 N 1079.0 E N 65.00 E 614.6 N 1144.9 E N 65.00 E 645.2 N 1210.5 E N 66.00 E 674.9 N 1275.8 E N 66.00 E 703.9 N 1340.8 E N 66.00 E N 70.00 E N 75.00 E N 76.00 E N 82.00 E 732.7 N 1405.6 E 759.5 N 1471.8 E 781.4 N 1541.7 E 800.5 N 1615.3 E 815.1 N 1690.5 E ^Survey Codes: 7/GYRO N 82.00 E 825.7 N 1765.6 E N 81.00 E 836.8 N 1840.1 E N 82.00 E 847.9 N 1914.6 E N 82.00 E 858.4 N 1989.2 E N 82.00 E 868.8 N 2063.2 E Page 2 06/29/92 CLOSURE DL DISTNCE BEARING /100 237.9 N 61.61 E 3.05 280.9 N 61.49 E 3.19 328.4 N 61.26 E 3.34 380.4 N 60.96 E 3.41 436.7 N 60.90 E 2.56 497.0 N 60.91 E 3.25 561.3 N 60.75 E 3.16 629.7 N 60.50 E 4.06 703.7 N 60.35 E 5.00 781.0 N 60.31 E 1.74 858.5 N 60.42 E 0.95 933.9 N 60.59 E 3.09 1007.4 N 60.80 E 0.78 1080.6 N 61.08 E 1.47 1153.8 N 61.37 E 0.73 1226.8 N 61.58 E 0.50 1299.4 N 61.77 E 0.25 1371.7 N 61.94 E 0.25 1443.3 N 62.12 E 1.04 1514.4 N 62.30 E 0.25 1585.1 N 62.47 E 0.25 1656.2 N 62.71 E 3.12 1728.4 N 63.12 E 4.06 1802.7 N 63.64 E 3.09 1876.8 N 64.26 E 4.92 1949.1 N 64.94 E 0.00 2021.4 N 65.55 E 1.06 2093.9 N 66.11 E 1.06 2166.5 N 66.66 E 0.75 2238.7 N 67.16 E 0.25 DS12-06A S MEAS INCLN C DEPTH ANGLE 7 5100 48.25 7 5200 48.00 7 5300 47.75 7 5400 47.50 7 5500 47.50 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 7 5600 47.00 7 5700 47.00 7 5800 46.25 7 5900 46.25 7 6000 46.00 4189.0 4115.0 788.6 N 81.00 E 4255.8 4181.8 829.5 N 81.00 E 4322.9 4248.9 870.2 N 81.00 E 4390.3 4316.3 910.3 N 80.00 E 4457.8 4383.8 950.8 N 82.00 E 7 6100 46.00 7 6200 45.75 7 6300 45.25 7 6400 45.50 7 6500 44.75 4525.7 4451.7 992.7 N 83.00 E 4593.9 4519.9 1035.0 N 83.00 E 4662.6 4588.6 1077.1 N 83.00 E 4731.7 4657.7 1119.3 N 84.00 E 4801.1 4727.1 1161.5 N 83.00 E 7 6600 45.50 7 6700 45.75 7 6800 45.00 7 6900 45.25 7 7000 46.00 RELATIVE-COORDINATES FROM-WELL-HEAD 7 7100 46.25 7 7200 46.50 7 7300 46.50 7 7400 46.00 7 7500 45.75 879.9 N 2137.0 E 891.5 N 2210.5 E 903.1 N 2283.8 E 915.3 N 2356.6 E 926.8 N 2429.4 E 7 7600 45.00 7 7700 45.50 7 7800 45.25 7 7900 43.50 7 8000 44.00 936.4 N 2502.2 E 945.3 N 2574.8 E 954.2 N 2647.0 E 962.4 N 2718.7 E 970.5 N 2790.4 E 4870.5 4796.5 1203.1 N 83.00 E 979.3 N 2861.8 E 4940.1 4866.1 1244.7 N 83.00 E 988.0 N 2933.0 E 5010.2 4936.2 1285.9 N 83.00 E 996.7 N 3003.8 E 5080.5 5006.5 1327.6 N 84.00 E 1004.8 N 3074.5 E 5151.0 5077.0 1369.5 N 84.00 E 1012.2 N 3145.0 E 5221.6 5147.6 1411.0 N 83.00 E 1020.2 N 3215.4 E 5291.5 5217.5 1452.4 N 83.00 E 1028.9 N 3286.3 E 5361.8 5287.8 1493.5 N 83.00 E 1037.6 N 3357.0 E 5432.3 5358.3 1534.5 N 83.00 E 1046.2 N 3427.3 E 5502.3 5428.3 1576.3 N 84.00 E 1054.3 N 3498.3 E 5571.6 5497.6 1619.0 N 84.00 E 1061.9 N 3570.0 E 5640.6 5566.6 1661.9 N 84.00 E 1069.4 N 3642.0 E 5709.4 5635.4 1704.9 N 84.00 E 1077.0 N 3714.2 E 5778.6 5704.6 1747.7 N 84.00 E 1084.6 N 3786.0 E 5848.2 5774.2 1790.2 N 84.00 E 1092.1 N 3857.4 E 5918.4 5844.4 1832.4 N 84.00 E 5988.8 5914.8 1874.5 N 84.00 E 6059.1 5985.1 1916.6 N 84.00 E 6130.5 6056.5 1958.1 N 84.00 E 6202.8 6128.8 1999.0 N 84.00 E ^Survey Codes: 7/GYRO 1099.5 N 3928.2 E 1106.9 N 3998.8 E 1114.4 N 4069.6 E 1121.7 N 4139.1 E 1128.9 N 4207.9 E Page 3 06/29/92 CLOSURE DL DISTNCE BEARING /100 2311.0 N 67.62 E 0.75 2383.5 N 68.04 E 0.25 2455.8 N 68.42 E 0.25 2528.1 N 68.77 E 0.78 2600.2 N 69.12 E 1.47 2671.7 N 69.48 E 0.89 2742.9 N 69.84 E 0.00 2813.7 N 70.18 E 0.75 2884.0 N 70.51 E 0.72 2954.3 N 70.82 E 0.76 3024.7 N 71.11 E 0.00 3095.0 N 71.38 E 0.25 3164.9 N 71.64 E 0.50 3234.5 N 71.90 E 0.75 3303.9 N 72.16 E 0.75 3373.4 N 72.40 E 1.03 3443.7 N 72.62 E 0.25 3513.7 N 72.82 E 0.75 3583.5 N 73.02 E 0.25 3653.8 N 73.23 E 1.04 3724.6 N 73.44 E 0.25 3795.8 N 73.64 E 0.25 3867.2 N 73.83 E 0.00 3938.3 N 74.01 E 0.50 4009.0 N 74.19 E 0.25 4079.1 N 74.36 E 0.75 4149.2 N 74.53 E 0.50 4219.4 N 74.69 E 0.25 4288.4 N 74.84 E 1.75 4356.7 N 74.98 E 0.50 1 1 1 1 1 1 ' ! I ' I ' '1 'l ! ! 1 - ! I 1 ! ! DS12-06A S MEAS INCLN C DEPTH ANGLE 7 8100 43.50 7 8200 44.00 7 8300 43.50 7 8400 42.25 7 8500 43.25 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY 7 8600 43.75 7 8700 44.00 7 8800 43.50 7 8900 44.50 7 9000 44.50 SECTION DISTNCE 7 9100 44.50 7 9200 43.75 7 9300 43.75 7 9400 42.50 7 9500 43.75 DIRECTION BEARING 7 9600 42.00 7 9700 43.75 7 9800 42.50 3 9822 42.60 3 10228 39.60 6275.0 6201.0 2040.0 N 84.00 E 6347.3 6273.3 2081.0 N 84.00 E 6419.5 6345.5 2121.7 N 83.50 E 6492.8 6418.8 2161.3 N 83.00 E 6566.2 6492.2 2200.8 N 83.50 E 3 10321 40.10 3 10412 40.30 3 10506 39.40 3 10600 38.60 3 10692 37.50 6638.7 6564.7 2240.8 N 83.00 E 6710.8 6636.8 2281.1 N 83.50 E 6783.1 6709.1 2321.9 N 84.00 E 6855.0 6781.0 2363.5 N 85.00 E 6926.3 6852.3 2406.3 N 85.50 E 3 10783 35.70 3 10869 33.90 3 10972 32.10 3 11065 31.40 2 11111 31.70 6997.6 6923.6 2449.5 N 86.00 E 7069.4 6995.4 2493.1 N 87.00 E 7141.7 7067.7 2537.2 N 87.50 E 7214.7 7140.7 2581.2 N 88.00 E 7287.6 7213.6 2625.0 N 87.00 E 7360.9 7286.9 2668.3 N 87.50 E 7434.2 7360.2 2711.9 N 87.50 E 7507.2 7433.2 2755.9 N 88.00 E 7523.4 7449.4 2765.6 N 88.00 E 7831.6 7757.6 2974.6 S 66.00 E RELATIVE-COORDINATES FROM-WELL-HEAD Page 4 06/29/92 CLOSURE DL DISTNCE BEARING /100 1136.1 N 4276.7 E 4425.0 N 75.12 E 0.50 1143.4 N 4345.4 E 4493.3 N 75.26 E 0.50 1150.9 N 4414.2 E 4561.7 N 75.39 E 0.61 1158.9 N 4481.8 E 4629.2 N 75.50 E 1.30 1166.9 N 4549.2 E 4696.4 N 75.61 E 1.06 1174.9 N 4617.5 E 1183.1 N 4686.3 E 1190.6 N 4755.1 E 1197.3 N 4824.2 E 1203.1 N 4894.1 E 1208.3 N 4964.0 E 1212.5 N 5033.5 E 1215.8 N 5102.5 E 1218.5 N 5170.8 E 1221.5 N 5239.1 E 1224.8 N 5307.1 E 1227.8 N 5375.1 E 1230.4 N 5443.4 E 1231.0 N 5458.2 E 1182.8 N 5715.7 E 7903.0 7829.0 3030.8 S 56.40 E 1154.1 N 5767.8 E 7972.5 7898.5 3087.8 S 56.50 E 1121.6 N 5816.7 E 8044.7 7970.7 3146.6 S 53.30 E 1087.0 N 5866.0 E 8117.8 8043.8 3204.6 S 53.60 E 1051.8 N 5913.5 E 8190.2 8116.2 3259.9 S 56.80 E 1019.4 N 5960.1 E 8263.3 8189.3 3312.2 S 58.80 E 8333.9 8259.9 3359.2 S 59.30 E 8420.3 8346.3 3413.4 S 54.60 E 8499.4 8425.4 3461.6 S 48.90 E 8538.7 8464.7 3485.6 S 48.23 E 990.5 N 6006.0 E 965.3 N 6048.1 E 934.7 N 6095.1 E 904.5 N 6133.5 E 888.5 N 6151.6 E 4764.7 N 75.72 E 0.61 4833.4 N 75.83 E 0.43 4901.9 N 75.94 E 0.61 4970.6 N 76.06 E 1.22 5039.8 N 76.19 E 0.35 5108.9 N 76.32 E 0.35 5177.5 N 76.46 E 1.02 5245.4 N 76.60 E 0.35 5312.5 N 76.74 E 1.30 5379.6 N 76.88 E 1.42 5446.6 N 77.00 E 1.78 5513.5 N 77.13 E 1.75 5580.7 N 77.26 E 1.30 5595.3 N 77.29 E 0.45 5836.8 N 78.31 E 4.25 5882.1 N 78.68 E 6.63 5923.9 N 79.09 E 0.23 5965.9 N 79.50 E 2.38 6006.4 N 79.91 E 0.87 6046.6 N 80.29 E 2.45 6087.1 N 80.64 E 2.37 6124.6 N 80.93 E 2.12 6166.3 N 81.28 E 3.04 6199.8 N 81.61 E 3.31 6215.4 N 81.78 E 1.00 ^Survey Codes: 2/MULTI SHOT 3/MWD 7/GYRO .... } 1 } I 1 1 ' 1 1 1 1 ! I I ! I I ! I ! DS12-06A RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 2 11203 29.96 2 11298 28.72 2 11392 27.88 2 11485 27.06 2 11579 26.60 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 8618.0 8544.0 3532.8 S 44.32 E 855.9 N 6185.8 E 8700.2 8626.2 3579.0 S 42.73 E 822.3 N 6217.6 E 8782.8 8708.8 3623.5 S 43.20 E 789.8 N 6247.9 E 8866.0 8792.0 3666.7 S 44.31 E 758.6 N 6277.8 E 8949.7 8875.7 3709.0 S 45.29 E 728.5 N 6307.6 E 2 11672 26.36 2 11687 26.22 9033.0 8959.0 3750.5 S 44.85 E 699.2 N 6337.1 E 9046.5 8972.5 3757.1 S 43.72 E 694.5 N 6341.7 E ^Survey Codes: 2/MULTI SHOT Page 5 06/29/92 CLOSURE DL DISTNCE BEARING /100 6244.7 N 82.12 E 2.87 6271.8 N 82.47 E 1.55 6297.6 N 82.80 E 0.93 6323.5 N 83.11 E 1.03 6349.6 N 83.41 E 0.68 6375.5 N 83.70 E 0.33 6379.6 N 83.75 E 3.46 I I ' 1 } ! ! ! ! 1 I 1 ~ } } 1 ! I i ~ } I DS12-06A DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL Page 6 06/29/92 SUBSEA DEPTH MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 100 174 0.00 174 0 0 N 0.00 E 200 274 0.00 274 0 0 N 0.00 E 300 374 0.00 374 0 0 N 0.00 E 400 474 0.00 474 0 0 N 0.00 E 500 574 0.00 574 0 0 N 0.00 E 600 674 0.00 674 0 700 774 0.93 774 0 800 874 2.92 874 0 900 974 4.06 974 0 1000 1075 6.12 1074 1 1100 1175 7.90 1174 1 1200 1277 9.05 1274 3 1300 1378 9.84 1374 4 1400 1479 9.80 1474 5 1500 1581 9.95 1574 7 1600 1683 10.62 1674 9 1700 1785 13.50 1774 11 1800 1888 17.32 1874 14 1900 1994 20.81 1974 20 2000 2103 24.08 2074 29 2100 2214 27.37 2174 40 2200 2328 30.65 2274 54 2300 2446 34.16 2374 72 2400 2570 37.77 2474 96 2500 2700 41.24 2574 126 2600 2839 47.19 2674 165 2700 2994 51.00 2774 220 2800 3151 48.97 2874 277 2900 3300 47.25 2974 326 3000 3447 47.25 3074 373 0 N 0.00 E 0 N 77.50 E 0 N 81.57 E 0 N 81.51 E 0 N 74.28 E 1 N 62.20 E 1 N 58.23 E 1 N 59.17 E 2 N 61.49 E 1 N 58.76 E 2 N 59.65 E 2 N 60.85 E 4 N 61.00 E 6 N 58.17 E 8 N 59.56 E 11 N 61.46 E 14 N 58.56 E 19 N 60.46 E 23 N 61.00 E 30 N 58.01 E 39 N 59.00 E 55 N 60.88 E 57 N 62.51 E 48 N 64.00 E 47 N 65.53 E RELATIVE COORDINATES FROM WELL HEAD 0.00 N 0.00 0.00 N 0.00 0.00 N 0.00 0.00 N 0.00 0.00 N 0.00 0.00 N 0.00 0.13 N 0.58 0.69 N 3.72 1.51 N 10.01 3.31 N 18.41 7.98 N 29.90 15.72 N 42.70 24.44 N 56.92 33.11 N 72.07 41.60 N 87.18 50.98 N 102.63 61.37 N 120.92 74.71 N 144.97 92.20 N 174.83 113.62 N 210.16 137.02 N 252.30 165.26 N 299.86 197.42 N 354.88 232.57 N 418.01 274.14 N 489.48 324.50 N 572.16 384.57 N 674.47 441.93 N 781.09 491.33 N 879.07 536.63 N 977.29 E E E E E E E E E E ! } } } ! I I I 1 ! 1 I 1 I " 1 I ~ ! ! DS12-06A DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL Page 7 06/29/92 SUBSEA DEPTH 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 3594 46.78 3174 420 47 N 65.00 E 3739 46.40 3274 465 45 N 65.00 E 3884 45.62 3374 510 44 N 65.84 E 4026 45.19 3474 552 42 N 66.00 E 4168 45.85 3574 594 42 N 68.72 E 4314 48.43 3674 640 47 N 75.14 E 4470 49.77 3774 696 56 N 80.21 E 4623 49.07 3874 749 53 N 81.77 E 4775 49.06 3974 801 52 N 81.75 E 4927 48.43 4074 853 52 N 82.00 E 5077 48.25 4174 903 50 N 81.23 E 5227 47.93 4274 953 50 N 81.00 E 5376 47.56 4374 1002 49 N 80.24 E 5524 47.38 4474 1050 48 N 82.24 E 5671 47.00 4574 1097 47 N 83.00 E 5816 46.25 4674 1142 46 N 83.16 E 5961 46.10 4774 1187 45 N 83.39 E 6105 45.99 4874 1231 44 N 83.00 E 6248 45.51 4974 1274 43 N 83.00 E 6391 45.48 5074 1317 42 N 83.91 E 6532 44.99 5174 1358 42 N 83.68 E 6675 45.69 5274 1401 42 N 83.00 E 6817 45.04 5374 1443 42 N 83.00 E 6959 45.70 5474 1485 42 N 83.59 E 7104 46.26 5574 1530 44 N 84.00 E 7249 46.50 5674 1575 45 N 84.00 E 7393 46.03 5774 1619 45 N 84.00 E 7537 45.47 5874 1663 43 N 84.00 E 7679 45.39 5974 1705 42 N 84.00 E 7821 44.88 6074 1747 42 N 84.00 E RELATIVE COORDINATES FROM WELL HEAD 581.94 N 1074.90 E 626.61 N 1170.69 E 670.13 N 1265.05 E 711.35 N 1357.58 E 751.32 N 1450.18 E 784.21 N 1552.10 E 811.60 N 1668.11 E 828.17 N 1783.07 E 845.28 N 1895.94 E 861.24 N 2009.24 E 877.25 N 2120.31 E 894.66 N 2230.45 E 912.24 N 2339.11 E 929.24 N 2446.87 E 942.72 N 2553.63 E 955.62 N 2658.80 E 967.20 N 2762.50 E 979.73 N 2865.34 E 992.25 N 2967.36 E 1004.09 N 3067.96 E 1014.64 N 3167.72 E 1026.74 N 3268.50 E 1039.09 N 3369.13 E 1051.18 N 3469.39 E 1062.12 N 3572.55 E 1073.11 N 3677.05 E 1084.06 N 3781.31 E 1094.82 N 3883.62 E 1105.35 N 3983.82 E 1115.93 N 4084.46 E DS12-06A DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL Page 8 06/29/92 SUBSEA DEPTH 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 7960 43.80 6174 1786 39 N 84.00 E 8099 43.51 6274 1825 39 N 84.00 E 8237 43.81 6374 1863 39 N 83.81 E 8375 42.57 6474 1901 37 ~ N 83.13 E 8511 43.30 6574 1937 36 N 83.45 E 8649 43.87 6674 1975 38 N 83.24 E 8788 43.56 6774 2014 39 N 83.94 E 8927 44.50 6874 2053 39 N 85.13 E 9067 44.50 6974 2093 40 N 85.83 E 9206 43.75 7074 2132 39 N 87.03 E 9345 43.19 7174 2171 38 N 87.72 E 9481 43.51 7274 2207 37 N 87.19 E 9618 42.31 7374 2244 36 N 87.50 E 9755 43.07 7474 2281 37 N 87.77 E 9890 42.09 7574 2316 36 S 87.61 E 10024 41.11 7674 2350 34 S 79.05 E 10156 40.13 7774 2382 32 S 70.61 E 10283 39.90 7874 2409 27 S 60.30 E 10414 40.28 7974 2440 31 S 56.43 E 10544 39.08 8074 2470 30 S 53.42 E 10672 37.74 8174 2498 28 S 56.09 E 10796 35.42 8274 2522 25 S 58.88 E 10917 33.06 8374 2543 21 S 57.11 E 11035 31.62 8474 2561 18 S 50.72 E 11152 30.92 8574 2578 17 S 46.48 E 11268 29.11 8674 2594 15 S 43.23 E 11382 27.97 8774 2608 14 S 43.15 E 11494 27.02 8874 2620 13 S 44.40 E 11606 26.53 8974 2632 12 S 45.16 E RELATIVE COORDINATES FROM WELL HEAD 1126.01 N 4180.36 1136.03 N 4275.71 1146.09 N 4371.05 1156.81 N 4464.73 1167.69 N 4556.45 1179.00 N 4651.10 1189.72 N 4746.52 1198.88 N 4842.83 1206.62 N 4940.80 1212.75 N 5037.84 1217.12 N 5133.16 1220.86 N 5226.15 1225.31 N 5318.92 1229.31 N 5412.68 1230.82 N 5504.34 1220.71 N 5592.15 1199.02 N 5673.83 1166.83 N 5747.17 1120.96 N 5817.78 1072.76 N 5885.21 1026.34 N 5949.68 986.54 N 6012.53 951.29 N 6070.61 914.51 N 6121.61 873.97 N 6167.38 832.94 N 6207.75 793.22 N 6244.74 755.65 N 6280.69 719.97 N 6316.29 ! ! ! ..... } 1 1 1 ! ! I I ! 1 1 ..... 1 1 .......... ! .......... ] ....1 DSl2-06A Page 9 06/29/92 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING iim DL/ 100 0 0.00 0 -74 1000 4.25 1000 926 2000 21.00 1979 1905 3000 51.05 2778 2704 4000 45.25 3456 3382 0 N 0.00 E 0 N 7 N 81.00 E 2 N 50 N 58.00 E 93 N 171 N 61.00 E 387 N 383 N 66.00 E 704 N 0 E 0 N 90.00 E 0.0 12 E 12 N 81.38 E 0.8 177 E 200 N 62.15 E 3.4 679 E 781 N 60.31 E 1.7 1341 E 1514 N 62.30 E 0.2 5000 48.25 4122 4048 747 N 82.00 E 869 N 6000 46.00 4801 4727 1162 N 83.00 E 971 N 7000 46.00 5502 5428 1576 N 84.00 E 1054 N 8000 44.00 6203 6129 1999 N 84.00 E 1129 N 9000 44.50 6926 6852 2406 N 85.50 E 1203 N 2063 E 2239 N 67.16 E 0.2 2790 E 2954 N 70.82 E 0.8 3498 E 3654 N 73.23 E 1.0 4208 E 4357 N 74.98 E 0.5 4894 E 5040 N 76.19 E 0.4 10000 41.28 7656 7582 2851 S 80.60 E 1223 N 11000 31.89 8444 8370 3428 S 52.88 E 926 N 5577 E 5709 N 77.63 E 4.3 6107 E 6177 N 81.38 E 3.3 P~DHOE BAY DR DS~2-O6A VERTICAL SECTION VIEN Section ac: S 42.33 E TVB Scale_: I inch = 300 feet Dep Scale.: i inch = 300 feet Draun ..... : 07/01/§2 ~aPkeP Identification ~B BKB SECTN INCLN A) TIE-IN / KBP 9822 75~3 ~76§ 42.60 B] TO I~687 9046 3757 26.22 ORIGINAL Sec[ion Departure PHdDHOE BAY DRILLING BBSO-,- 9000- 9300 9450- - 9600 ........................ 9750- ~.oo , I ,I, ~oo ~so ~oo DS 2-OGA VERTICAL SECTION VIEH I 2850 I 3000 Section at: TVD Scale.: Dep Scale.: Drawn ..... : S 42.33 E 1 inch = 300 feet ! inch = 300 feet 07/01/92 Sreat Land D~rectlonal O~ll~n~ Marker Identification MD BKB SECTN INCLN A} TIE-IN / KOP 9822 7523 2766 42.60 B) TO 11687 9046 3757 26.22 3t50 3300 3450 __Sect ion Oepart_u. re \\ ....................................... .......... _X<XB<~ \ \ \ X~xORIGINAL W LL I 3900 4500 3600 3750 4050 4200 4350 <- HJ.BON : HbgOS -> } } } } ! } } ! 1 ! i 1 } ! ! ! } } CLOSURE ..... : OECLINATION.: SCALE .......: DRAWN .......: Sreat Land D~rect~ona] ~ll~n9 13S -0[ PLAN VIE~ ,,,, ,,,,,.,,,, ,,, ,,,, ,, ,, 6380 fL at N 83.75 E 30.20 E ~ inch = 800 feel 07/0~/92 ..... P' u'"ON'oE BA'Y' Marker Identification MD N/S E/H ~) KB 0 0 N 0 E BI TIE-IN / KOP 9822 ~23! N 5458 E C) TO ~667 694 N 6342 E BRILLING ....... _- 400 0 400 800 <- NEST' EAST -> SIDETRACK I~ELL t200 &600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 P~£ ~, ORIGINAL - WELL HF~ IJr~?ION: LATin-S) 0,00 AZIW. rrH FROI~ ROTARY TABU TO T~(G~ IS TIE IN POINT(TIP) : ~ ~vrd TRU~ U~T DEPTH 7523.00 INCLINATION 42.&1 AZI~trIH LATI1'I~E(I,I/-S) 1231.00 D~ARTUR~(~-W) 545~.00 137.70 P~E XO. ~ I~ VEFd'ICAL ft ft ft 9822.00 0,0 7b'~3.00 10228,00 406.0 7031.15 10321.00 ?3,0 7902.62 10412.00 91,0 7972.12 1050~,00 94,0 8044,30 10600.00 10692°00 10703.00 108~9,00 10961.00 110~.00 11160.30 11253.20 11345.00 TARG~ STATION AZINJTH S{~I'ION 114CUi, it ~e~ 2762.82 42.61 2971.77 :39.60 I14.00 9020.00 40.10 123.50 3143.71 ~.40 126.70 DS 94,0 8117.3~ 3201.~ 38.60 126,40 92,0 8189.60 :3257.25 37.~ 123,20 91.0 8262.47 3309.78 ~.70 121 86.0 8333.08 3356.78 33.~ 120.70 92,0 8410,02 3405,0~ 32.60 121,20 10~o0 ~.40 94.3 8580.91 92.9 8,~1.53 91.8 8740.91 LATITUD£ D~ARTI~ DISPLACIII)IT at AZIRUTH N/-S EY-W ft ft 1231.00 II82,80 5715.51 1154,19 5767.61 1121.77 5816,59 1~7.16 ~5,87 ft d~ lOOft ~.10 77.2? O.OQ 5836.&1 78.31 4.5 ~881.96 78.58 6.~6 5923.78 79.0~ 0,22 5965.76 79,50 2.3,1) 1051,93 5~I3.39 1019.42 5960,14 990.36 6006,24 965.11 6048,33 939,17 6091.59 60(0,~ 79.91 0,87 60~.~? 80.29 2,28 6087,34 80,&4 2.7~ &124.~ ~0.93 2.12 6163.57 81.24 1,44 3457.98 30.70 121,~ 910.39 3504.01 29.70 125.96 883.99 3549.21 ~9,90 125,90 856,90 3594,49 30.40 127.?0 829,21 6138,57 6177.94 6215,33 6252,19 6205,71 81.56 1,83 6240.87 81.~ 2,46 6274,12 82,1b 0,22 6306.94 82,45 1,22 .~ . ANADIRILL 1 CINNABAR LOOP r.,NCHORAGE, ALASKA 99507 {907) 349-6575 Prudhoe Bay Unit P.O. Box 196612 Anchorage, AK 99519-6612 Attention: Terry Jordan June 22, 1992 Dear Terry, I have compiled a summary of Anadrill's performance on DS #12-6A SERVICES PROVIDED Directional MWD with DWOB and DTOR were picked up on 09-JUN-92 to assist with the casing milling operation. On 11-JUN-92 the same tool was used to successfully kick off the well. Due to some problems with the DWOB sensor which occurred after the angle and direction were established the tool and collar were changed out for the rotary run. At 11,445' we became stuck while on bottom drilling ahead. Two attempts were made to fish the BHA but were unsuccessful. The BHA including the MWD tool was left in the hole. The hole was cemented back to 10,780' and sidetracked on 21-JUN-92 with a DSS only tool. The sidetrack was completed on 22-JUN-92 at 11,187'. The motor and the MWD tool were laid down. .IOB PERFORMANCI~ DSS with downhole Weight on bit and downhole torque (DWOB/DTOR) was picked up with a casing mill, after 4 Unsuccessful attempts to mill a window as a way of checking to see if we were getting any weight to the mill. As you know mills are run with very light weight on bit, (2-6k), DWOB showed that no weight was reaching the mill at those surface weights. In fact only when 25k surface weight was used did any reach the mill. At this point things broke loose and the mill began to work with an average of 15k SWOB to get a DWOB of 5 to 7k. Though even higher weights were used on the previous run (30k) they were reached only after 3 or 4 hours of attempted milling. We think that this rotating in one place for a long time wore a groove in the casing which kept the weigh from reaching the mill even at 30k. With DWOB in the hole it was immediately apparent that no weight was being transferred, so little time was wasted trying to mill at light weights. As on previous wells DWOB and DTOR were used to increase the efficiency of the kickoff. All went very well. DWOB was even more important than usual because of the softness of the cement plug. At 10,400' DWOB quit working properly but DTOR was not affected. By this depth the angle and direction were established so the DWOB problem did not effect the kickoff. Because of weight transfer problems up hole the company man decided to run DWOB and DTOR on the rotary run. Unfortunately we became stuck while drilling ahead and lost the BHA. It occurred while on bottom drilling ahead. The rotary table stalled out about 10 feet into the top of the Sadlerochit, and when the driller tried to pick up off bottom we were mechanically stuck. DWOB and DTOR indicted that we were stuck below the MWD tool probably at the combo too!. SFT was spotted with no results. Up until the time the SFT was spotted the BI-IA was free past the MWD tool. Once the SFT was pumped we did not pump fast enough to turn the MWD tool on. By the time a backoff attempt was made the BI-IA was stuck at the top stabilizer. Two attempts were made with different fishing jars to free the BI-IA but we were unable to free it. A cement plug was set and the well was sidetracked. The first attempt to sidetrack the well at 10,850' failed due to the cement becoming very soft. We rotary drilled to 10,951' and successfully sidetracked the well at this point with Directional Survey Service, (DSS) pulled out of hole and laid down the MWD tool and the motor. For your convenience, I have included an ASCII file of the surveys along with a hardcopy of the surveys. I have also included a copy of the sticking pipe indicator (SPIN) log. Anadrill appreciates the opportunity to supply services on your well and we look forward to continuing a healthy business relationship. Thank you, .,°"~.RRY-SUN DRILLING SERVICES--~ ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-6A 500292040101 NORTH SLOPE COMPUTATION DATE: 07/06/92 DATE OF SURVEY: 062592 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-20039 KELLY BUSHING ELEV. = 74.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST VERT. SECT. 9822 7523.00 7449.00 42 36 N 88.00 E .00 1231.00N 5458.00E 10272 7865.55 7791,55 39 45 S 60,33 E 4.64 1164.33N 5738.49E 10367 7938.26 7864.26 40 12 S 56.32 E 2.76 1132.32N 5790.34E 10459 8009.25 7935.25 39 54 S 55,17 E .87 1098.73N 5839.67E 10553 8081.48 8007.48 39 8 S 54.28 E 1.01 1064,33N 5888.31E 5559.73 5831.27 5879.32 5924.68 5969.28 10645 8153.16 8079.16 38 40 S 57.49 E 2.25 1031.89N 5936.19E 10739 8227.50 8153.50 36 26 S 59.83 E 2.82 1002,14N 5984,98E 10832 8303,25 8229.25 34 23 S 60.27 E 2.22 975.25N 6031.64E 10924 8380.24 8306.24 32 56 S 58.21 E 1.99 949,04N 6075,71E 11018 8459,31 8385,31 31 55 S 53,28 E 3.02 920,81N 6117,21E 6013,33 6058.59 6102.04 6142.98 6181,16 11111 8538.24 8464.24 31 10 S 48.23 E 2,97 890.21N 6154.71E 11203 8617,75 8543,75 29 57 S 44.32 E 2.52 857,79N 6188.65E 11297 8700.01 8626,01 28 43 S 42.73 E 1,55 824,28N 6220,49E 11391 8782,56 8708,56 27 52 S 43.20 E .93 791.75N 6250.79E 11485 8865,78 8791.78 27 3 S 44.31 E 1.03 760.49N 6280.70E 6215.10 6245.29 6273.29 6299.85 6326.18 11579 8949.43 8875.43 26 36 S 45.29 E .68 730.47N 6310.51E 11672 9032.80 8958.80 26 21 S 44,85 E ,33 701.14N 6339.92E 11687 9046.25 8972.25 26 13 S 43.72 E 3.46 696.39N 6344.55E 6352.54 6378.57 6382.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6382.66 FEET AT NORTH 83 DEG. 44 MIN. EAST AT MD = 11687 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 83.74 DEG. SPERRY-SUN DRILLING SERVICF~ ANCHORAGE ALASKA PA~ PRUDHOE BAY DRILLING PBU/12-6A 500292040101 NORTH SLOPE COMPUTATION DATE: 07/06/92 DATE OF SURVEY: 062592 JOB NUMBER: AK-EI-20039 KELLY BUSHING ELEV. = 74.00 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH MEASD DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINAT DEPTH DEPTH NORTH/SOUTH EAST/WE ES MD-TVD VERTICAL ST DIFFERENCE CORRECTION 9822 10822 11687 7523.00 7449.00 1231.00 N 5458,00 E 2299.00 8294.73 8220.73 978.14 N 6026,58 E 2527.27 228.27 9046,25 8972.25 696.39 N 6344.55 E 2641.00 113.74 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. FT. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-64 500292040101 NORTH SLOPE COMPUTATTON DATE: 07 /06/92 DATE OF SURVEY: 062592 JOB NUMBER: AK-El-20039 KELLY BUSHING ELEV. = 74.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIF MD-TVD VERTICAL FERENCE CORRECTION 9822 7523,00 7449,00 1231,00 N 5458,00 E 9890 7574,00 7500,00 1230,77 N 5504,06 E 10023 7674,00 7600,00 1220,22 N 5589,89 E 10153 7774,00 7700,00 1196,74 N 5670,00 E 2299,00 2316,73 17.73 2349,00 32,27 2379,33 30,32 10283 7874.00 7800.00 1160.81 N 5744.59 E 10413 7974.00 7900.00 1115.53 N 5815.42 E 10543 8074.00 8000.00 1067.88 N 5883,37 E 10672 8174,00 8100,00 1023,13 N 5950.12 E 10796 8274.00 8200,00 985.20 N 6014,22 E 2409.21 29.89 2439.87 30.65 2469.83 29.96 2498.14 28.31 2522.85 24,71 10917 8374,00 8300,00 951,17 N 6072,27 E 2543,40 20.54 11035 8474,00 8400,00 915,29 N 6124,46 E 2561,78 18.39 11152 8574,00. 8500,00 875,78 N 6170,74 E 2578,86 17.07 11268 8674,00 8600,00 834,74 N 6210,82 E 2594.15 15,29 11381 8774,00 8700,00 795,05 N 6247,69 E 2607,88 13.73 11494 8874.00 8800.00 757.49 N 6283.64 E 2620.60 12.71 11606 8974,00 8900,00 721.82 N 6319.26 E 2632.59 11.99 11687 9046,25 8972.25 696.39 N 6344,55 E 2641,00 8.42 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-31-92 REFERENCE: ARCO CASED HOLE FINALS 1-4 ~ ~>~ 7-12-92 CCL/Perf Run 1, 5" Atlas 1-13 ?~ 7-18-92 CCL/Perf Run 1, 5" Atlas 2-31 7-6-92 Prod/Press/Spin/Temp/Trap Run 1, 5" Sch 3-10 2~--~7 7-6-92 CCL/Perf Run 1, 5" Atlas 3-35 7-13-92 CCL/Perf Run 1. 5" Atlas 9-9 ~/("~ 7-12-92 CCL/Perf Run 1, 5" Atlas 9-11 ?~P~/ 7-13-92 CCL/Perf Run 1, 5" Atlas 11-7 g/-/~ 7-11-92 CCL/Tubing Cutter Run 1, 5" Atlas 111-16ST 5-30-92 MAI Acoustic Filtered Waveforms Run2,~' Atlas 11-16ST 5-30-92 BHC MAI Comp Slowness Curves Run 2, :~' & ~' Atlas 12-6A~.~--~e'~/7-11-92 PFC/GR Run 1, 5" Atlas 15-9 7-13-92 Collar/Perf Run 1, 5' Atlas 15-28 ~ ~/~ 7-12-92 PFC/GR. Run 1, 5" Atlas 17-3 7-12-92 CCL/Perf Run 1, 5" Atlas NGI-11 7-19-92 CCL/Tubing Cutter Run 1, 5" Atlas Please sign and return the attached copy as receipt of data. RECEIVED BY .~~~_~___ APPROVED ~ Trans# 9217~- [ Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED AUG 1 0 199~ Alaska Oil & Gas Cons. commission AnchOrage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO DIRECTIONAL DATA c6-14A / 6-26-92 ~12-6A '~ ~-25xJ2 / MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Job#AK-EI-20042 Job#AK-EI-20039 Job#AK-MW-20040 Please sign and return the attached copy as receipt of data. RECEIVED BY ~ Have A Nice Day! Sonya W_~ll~ce AT0-1529 APPROVED Trans# 9215~-7 .... Ana Sperry Ana Sperry Sperry CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL PHILLIPS # PB WELL FLS (2 COPIES) R&D # BPX # ST. OF AK. (2 COPIES) TEXACO AOGCC GEOLOGICAL MATERIALS iNVENTORY' LiST PERMIT # ~ - ,-~',~ WELL NAME ,~ COMPLETION DATE ? //? t ~"'~' CO. CONTACT ... ~hcCk'off or list data a's' it is 'i:~Ceived'?list received date for 407. if not re~]'ui~ed Ii'st as NR cored intc~al.s core.' .anal,vsi.s . .J~,~,. ditch intervals di _ data ,,, ,/,,.,~ ............. ,v'~ , , ~31~ (~ H9 NO. [to thc .nearest footI .... linch/100'1 . , " i i ,,i iii1,1 ii iiii i i i iii i i 71 . ARCO .~l_~ska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO OPEN HOLE FINALS ( 6-14A 6-25-92 t 6-14A 6-25-92 ~ 7 ~12-6A 6-25-92 (~15-28 6-29-92 6-23*92 1 6-23-92 SSTVD / Run BHCA/GR ~ Run DLLfMII./GR ~ Run BHCS/GR (Color) ~//Run DLL/GR -/ Run SSTVD ,/ Rim DLL/GR -~ Run BH~A/GR ~/ Run CNL/GR ~/ Run SSTVD ~/ Rnn CNL/LDT (~aw) ~/ mm CSL/LDT/Poro) ~/ ram 1, 1" & 1,2'& 1, 1~' & 1, :~'& 1,2'& 1, 1" & 1, i~'& 1, ~' & 1, Il"& 1, l"& 1, :~'& 1, 2" & 1, 2" Atlas ~Y' Atlas ~Y' Atlas ~Y' Sch ~" Sch 2' Atlas ~Y' Atlas ~' Atlas lY' Atlas 2" Sch [Y' Sch fY' Sch 5" Sch Please sign and return the attached copy as receipt RECEIVED BY ~__~ Have A Nice Day! ~: ~ Fi V E ¢ Sonya Wallace ATO-1529 JUL I ~ 1992 of data. APPROVED_ ~_ffffff Trans# 92148 Alaska Oil & Gas Cons. Commission # CENTRAL FIL~h°rage # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS # PB WELL FILES R&D # BPX # STATE OF .ALASKA # TEXACO ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ~?/_~' 14-19ST / ARCO MAGNETIC TAPE(S) WITH LISTINGS 6-25-92 DLLIM~.r. IACIGR"~(/~3-3/~' Rnn I Job~ 102257 Atlas ~2.5,-~ BCS/DLL ~ j- ~/~(,. ~ 1 Job~ 92389 Sch 6-13-92 DIFL/AC/CN/GRer- ?/d~ Run I Job~ 102254 Atlas +23-/)2 DTE/SDN/CNTH/GR.~7/.,..,~,,.,/ Run1 Job~92380 Sch Please sign and return the attached copy as receipt of data. ,EOE,VE Have A Nice Day.' Sonya W._ll. ce AT0-1529 dUL 1~ t992 Alaska Oil & Gas Cons. Commission CENTRAL FILES (CH) CHEVRON D&M # DEDE SCHWARTZ (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C Commission~ Blair Wondzell6~~2~g P.I. Supervisor Harold R Hawkins Petr Inspector DATE: FILE NO: TELEPHONE NO: SUBJECT: June 23, 1992 hh623-3.doc Rig/BOPE Inspection Doyon 16, PBU 12-6A Permit No. ~ ~-~ - Prudhoe Oil Pool ~J~- Wednesday. Jun~ 17, 1992 i made a riq/BOPE inspection of Doyon 16 at PBU 12-6A. There were no infractions. I filled out an AOGCC field report which is attached. In summary, the rig/BOPE inspection of Doyon 16 at PBU 12-16A was satisfactorily performed. Attachment 02-00lA (Rev. 6/89) 20/1UMEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,JN BOPE Walk-Thru Inspection Report Operator _~). j~ ~) Permit # ~--/~3-~-~;/ Representat/~ve Location: Sec ~ T,~OM Rl~ M M _, ~ell name J ~-"~ Rig~ /~ Representative Drlg contr ~Z~/~)/A ~ Location (gen'l) ~/~ I N COMPL I ANCE; y,es no nra A. DlVERTER 1. ( ) ( ~ ( ~ () 2. () 3. () ,~. () 5.(~) () 6. ( ) 7. ({/~. ( ) 8.(~ () 9. (~ ( ) lo.(~ ( ) ~.(/), () 13. ( ) 15. ( ) 1. (~ ( ) 2 ( () 4.(~ () () 6.(~ () 7. ( ( ) 8.(0 () 9.(~ () lo ( ( ) REMARKS: Well sign ((( ) line sz & length ( ) line conn& anchored / ( ) bifurcated & dwn wind ) 90° targeted turns (\)) vlvs: auto & simultaneous annular pack-off ( ) condition B. BOP STACK { ) wellhead flg wkg press ( ) stack wkg press ( ) annular preventer ( ) pipe rams ( ) blind rams ( ) stack anchored ( ) chke/kill line sz , ( ) 90° turns targeted (chke & kill ln) ( ) HCR vlvs (chke & kill) ( ) manual vlvs (chke & kill) ( ) connections (flgd, whd, clmpd) ( ) drl spool ( ) flow nipple ( ) flow monitor ( ) control lines fire protected C. CLOSING UNITS ( ) wkg press ( ) fluid level ( ) oprtg press ( ) press gauges ( ) sufficient vlvs ( ) regulator bypass ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel ( ) remote control panel IN COMPLIANCE; yes nc) 9!a 11. (~ ( ) 12 ((~v, () 13 ( ) 1.(W () ~. (v~ '() 3. iv) () s () 1.((() 3.(~ (1 4.( () s. (~/ ( ) 6.( () 7. (/() 8.( () 1. (~ () 2.( () () s.. () 7. () ( ) firewall ( ) nitrogen power source (back-up) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM ( ) pit level floats installed ( ) flow rate sensors ( ) mud gas separator ( ) degasser ( ) separator bypass ( ) gas sensor ( ) chke In conn ( ) trip tank E. RIG FLOOR ( ) kelly cocks (upper,lower,IBOP) ( ) floor vlvs (dart vlv, ball vlv) ( ) kelly & floor vlv wrenches ( ) driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) (') kill sheet up-to-date ( ) gas etection monitors (H~S & methane) ( ) hydr chke panel ( ) chke manifold F. MISC EQUIPMENT ( ) flare/vent line ( ) 90° turns targeted (dwn strm choke 1ns) ( ) reserve pit tankage ( ) personnel protective equip avail ( ) all dr] site suprvs trained 2for procedures ( ) H S probes ( ) rig housekeeping RECORDS: ~ Date of last BOP inspection: ,, Resulting non-compliance: l Non-compliances not corrected & why: .~//~- Date corrections will be completed: BOP test & results properly entered on daily record? Date of last BOP test: Kill sheet current? C.0013 (rev 03/29/91) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 28, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 AnchOrage, Alaska 99519-6612 Re: Prudhoe Bay Unit DS 12-6A ARCO Alaska, Inc. Permit No: 92-54 Sur. Loc. 579'NSL, 19'WEL, Sec. 18, T10N, R15E UM Btmhole Loc. 4130'SNL, 4067'WEL, Sec 16, T10N, R15E UM Dear Mr. Zanghi: 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 witness 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. David W. j~sto~~ 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 ~JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll;'lllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 73'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchora~Te. Alaska 99519-6612 ADL 28331 4. Location of well at surf-ace 7. Unit or property Name 1 1. Type Bond(see 20 AAC 25.025) 579' NSL, 19' WEL, SEC. 18, TION, R15E Prudhoe Ba~/ Unit At top of productive interval 8. Well number Number 3919' SNL, 4260' WEL, SEC. 16, TION, R15E DS 12-6A U-630610 At total depth 9. Approximate spud date Amount 4130' SNL, 4067' WEL, SEC. 16, TION, R15E 6/5/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28330/1212 feet DS 12-25/1800' @ 10000/feet 2560 feet 16. To be completed for deviated wells 17. Anticipated pressure (s,,e 20 ,~c 25.035 Kickoff depth ~oosofeet Maximum hole angle 45 o Maximum surface 3330psig At total depth (TVD) 8800'/4~9~)psi[j 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" rend. Weld 73' Surface 73' 73' 400 sx Arcticset II - 17-1/2" 13-3/8" 72# L-80 Butt 2899' Surface 2899' 2714' 2500 sx Permafrost II - 12-1/4" 9-5/8" 47# L-80 NSCC 12413' Surface 12413' 9444' 1578 sx Class "G" - J 8-1/2" 7" 26# L-80 IJ4S 1250' 9800' 7506' 11050 8474' 8-1/2" 7" 26# 13cr80 Fox 880' 11050' 8474' 11930' 9169' 371 sx Class "G" ,19. TO be completed for Redrill, Re-entry, and Deepen Operations. ~, !: ~ !:: ! V !:: !) Present well condition summary Total depth: measured 12466feet Plugs (measured) true vertical BKB 9468 feet MAY 2.6 1992 Effective depth: measured 12200feet Junk (measured) Alaska 0il & Gas Cons. true vertical BKB 9398feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 73' 20" 400 sx Arcticset II 73' 73' Surface 2899' 13-3/8" 2500 sx Perm. II 2899' 2714' Intermediate Production 12413' 9-5/8" 1578sx Class "G" 12413' 9444' Liner Perforation depth: measured 11600'-11640',11648'-11694',11704'-11749',11830'-11832' true vertical 8846'-8874',8880'-8913',8920'-8953',9013'-9014' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby certi~f~,.j.y tl3at~e~Tis true and correct to the best of my knowledge Signed~t.L¢//-~~'' ~/~//~.-,,~,,,.- ~ Title Dr/fling En~7ineer Supervisor Date~''~- ~'~' (,../' /,,) Commission Use Only L,~ Permit Number IAPI number IApproval date ISee cover letter ~'..~ '.-',~ ~// J50-0.2_'~- .Z.~::~ ~7"o/-0/ I ~_.x.--_.,~_~ Ifor other requirements Conditions of approval Samples required [] Yes ...l~'No Mud log rec~uired [] Yes~l~ Hydrogen sulfide measures [] Yes ~ No Directional survey required ,,~ Yes [] No Req. jzLr. ed--w4zd~~r~2M; 1-13M; 1~5M; I-IIOM; F'115M; by order of Approve~ ~, ._"~.,...~)',,~ ~ Commissioner [ne commission Date Form 10-401 Submit ir PRELIMINARY WELL PLAN WELL: 12-6A Redrill PBU APl No.: 50-029-20401-00 (on the original 12-6 well) LOCATION: Surface: 579' FSL, 18' FEL, Sec. 18, T10N, R15E Target: 3919' FNL, 4260' FEL, Sec. 16, T10N, R15E @ 8728' ssTVD BHL: 4130' FNL, 4067' FEL, Sec. 16, T10N, R15E @ 9095' ssTVD ESTIMATED START: 5 June, 1992 .OPR. DAYS TO COMPLETE: 15 (5 days prep & mill, 5 days drill, 5 days complete) CONTRACTOR: Doyon Rig #16 DIRECTIONAL' Kickoff at 10050' MD. 5 degree angle drop and 45 degree south turn. WELLBORE: Item TVD(BKB) .MD(BKB) Mud Wt. 20" CONDUCTOR 11 0' 11 0' N/A 13-3/8" SHOE 271 3' 2899' N/A KOP 9148' 10050' 9.3 TOP SAG RIVER SANDSTONE 8702' 11339' 9.5 TOP SADLEROCHIT 8802' 11465' 9.5 TOTAL DEPTH 91 69' 11 930' 9.5 LOGGING PROGRAM: 8-1/2" Hole: MUD PROGRAM: Resisitivity / Gamma Ray / SP / Sonic / Neutron Alaska. 0il & Gas Cons. 'Anchorage The milling/drilling fluid program will consist of a 9.3 - 9.5 ppg XCD polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY (TVD) (PPG) 7690' 9.3 to to 9169' 9.5 PV YP INT 10MIN FL OIL SOLIDS MUD (CP) (#/FT) GEL GEL CC/30min (%) (%) TYPE 1 0 1 0 5 7 8 0 5 Water to to to to to to to Base 16 18 10 15 5 0 7 Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.5 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 4075 psi/8628' ss TVD. 3600 psi/8800' ss TVD. Overbalance Sag River: Overbalance Top Sadlerochit: 224 psi. 747 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST (;;OLLAPSE TEN~!LF 7240 psi 5410 psi 604 klbs 7" 26# 13CR-80 FOX 7" 26# L-80 IJ4S CEMENT 7" LINER: 11050'-11930' MD (8474'-9169' TVD) 9800' -11050' MD (7506'-8474' TVD) CALCULATIONS: Measured Depth: Basis: 7240 psi 5410 psi 567 klbs 9800' (Hanger) - 11,930' (Shoe) Total Cement Vol: 35% open hole excess, 40' shoe joints, 250' liner lap and 200' excess above liner with DP. 430 cuft or 371 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 3-1/2" 9.2# 13CR-80 Fox (9700' - 11,930' MD) 4-1/2" 12.6# 13CR-80 Fox (0'- 9700' MD) DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT _ _ _ _ _ _ 8 g _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 H P agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console ROPOSED REDRILL PROGR J WELL 12-6A OBJECTIVE: The primary objective the the 12-6A Redrill is to increase production by drilling a new hole to a location about 600' SSW of the current BHL. A short redrill is preferable to RWO options based upon the cost and the risk associated with a successful cement squeeze. The scope of work is as follows: Plug and abandon the existing perforations using CTU. Cut the tubing above the top of the packer prior to arrival of the workover rig, Pull the 5- 1/2" 17# L-80 PC tubing completion, Test the 9-5/8" wellhead pack-off and replace it and tubing head if needed, Set a bridge plug in the casing. Mill a section in the 9-5/8" casing. Lay a cement plug below and across the section. Kick-off and drill a new 8-1/2" hole to TD of 120' MD below the OOWC at 9000' ss and about 600' departure south- southwest from the current wellbore at target depth (top of Sadlerochit) of 8728' ss. Run wireline conveyed open hole logs, Install a 7" L-80 / 13CR liner. Retest / replace the wellhead packoff as needed. Recomplete with 4-1/2" x 3-1/2" 13CR tubing. The Zone 4 objective interval will be perforated after the rig moves off of location. CURRENT STATUS: Well 12-6 is currently only producing 250-300 BOPB intermittently at a 80-90% watercut. The well has been squeezed in an attempt to shut-off water and ongoing scale problems have required HCI treatments. The 12-6 was drilled in 1979 with the Parker #176 rig. The current wellbore has 13-3/8" surface casing set at 2899' MD / 2713' TVD and 9-5/8" production casing set at a total depth of 12,413' MD / 9431' TVD. The well was completed with a 9-5/8" packer and 5- 1/2" tubing. PERMITTING: The attached sundry notice covers the plagback of the original well and the drilling permit covers the proposed drilling program. I £C£1vEo Alaska Oil & Gas Cons. AnChorage. .71OPOSED REDRILL PROGR. _, WELL 12-6A SUMMARY PROCEDURE: , , , . , ! 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Plug-back existing perforations with cement, plug tailpipe and cut tubing at 10,500' MD above the production packer prior to arrival of the workover rig. MIRU workover rig. Pull 5-1/2" BPV. Circulate freeze protection fluid from well and recover for future use. Set two-way check valve. Remove the tree. Install and test BOP's. Pull two-way check valve. Pull the 5-1/2" 17# L-80 PC tubing completion. Test 9-5/8" packoff in the Gray GEN-II wellhead to 3000 psi. Replace it and tubing head if necessary. RIH and set a 9-5/8" bridge plug at 10,300' MD. RIH with section mill. Spot a 17 ppg pill on bottom and cut 60' from the 9-5/8" casing starting at 10,050' MD. Set a cement kick-off plug from 100' below base of section to 200' above top of the section. Run in the hole with a steerable, directional drilling assembly and dress off the plug to 5' below top of section. Kickoff through the section and directionally drill to TD of 120' MD below the OOWC at 9000' ss and about 600' departure south-southwest from the current wellbore at target depth (top of Sadlerochit) of 8728' ss. Run wireline conveyed open hole (GR/DIL/CNL/BHCS)logs. Install and cement 7" L-80 / 13CR liner from TD to 250' above top of the section. Clean out liner to PBTD, displace well to inhibited, filtered seawater (if unable to displace cement with seawater) and test to 3000 psi. RIH with 4-1/2" x 3-1/2" 13CR completion assembly. Space out and land tubing hanger. Drop packer setting ball and pressure tubing to set 7" 13CR production packer. Test tubing to 3000 psi. Test tubing x casing annulus to 2500 psi. Pressure annulus to shear RP reverse circulating valve. Set two-way check valve. Remove BOP's. Replace tree and test to 5000 psi with diesel. Pull two-way check valve. Displace diesel (or other freeze protection fluid) down annulus and U-tube into tubing to freeze protect to a depth of 2000' MD. Set BPV. Release rig. Well will be perforated through tubing after rig has moved off of location. GREAT L~_ND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : 12-06A (P3) Prepared ..... : Field ........ : PRUDHOE BAY Section at...: Computation..: MINIMUM CURVATURE KB elevation.: LOCATIONS LEGAL DESCRIPTION X ASP ZONE 4 Y Surface ...... : 578 FSL 20 FEL S18 T10N R15E UM 697587.00 5930909.00 Tie-in ....... : 1814 FSL 318 FWL S16 T10N R15E UM 703165.69 5932294.05 Target ....... : 1361 FSL 1019 FWL S16 T10N R15E UM 703880.00 5931860.00 BHL .......... : 1150 FSL 1211 FWL S16 T10N R15E UM 704077.69 5931654.31 PROPOSED WELL PROFILE 05/20/92 S,53.42,E 74.00 ft STATION IDENTIFICATION TIE-IN END DROP & TURN KINGAK SAG RIVER SHUBLIK SADLEROCHIT TARGET OWC HOT TD KAVIK MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES DL/ BEARING FROM-WELLHEAD 100 10050 42.62 7690 7616 3771 N 87.51 E 1237 N 10100 41.73 7727 7653 3798 S 89.82 E 1237 N 10200 40.15 7803 7729 3852 S 84.22 E 1234 N 10300 38.85 7880 7806 3908 S 78.27 E 1224 N 10400 37.86 7958 7884 3966 S 72.02 E 1208 N 10500 37.23 8038 7964 4025 S 65.54 E 1186 N 10600 36.95 8117 8043 4084 S 58.92 E 1158 N 10700 37.04 8197 8123 4144 S 52.27 E 1124 N 10800 37.50 8277 8203 4204 $ 45.71 E 1085 N 10853 37.89 8318 8244 4236 S 42.33 E 1062 N 11050 37.89 8474 8400 4355 S 42.33 E 972 N 11339 37.89 8702 8628 4529 S 42.33 E 841 N 11371 37.89 8728 8654 4549 S 42.33 E 826 N 11465 37.89 8802 8728 4605 S 42.33 E 783 N 11465 37.89 8802 8728 4605 S 42.33 E 783 N 11639 37.89 8939 8865 4710 S 42.33 E 705 N 11753 37.89 9029 8955 4779 S 42.33 E 653 N 11930 37.89 9169 9095 4885 S 42.33 E 572 N 9338 9264 5614 E <TIE 5647 E 4.0 5713 E 4.0 5776 E 4.0 5835 E 4.0 5892 E 4.0 5946 E 4.0 5995 E 4.0 6041 E 4.0 6063 E 4.0 6145 E 0.0 6264 E 0.0 6278 E 0.0 6316 E 0.0 6316 E 0.0 6388 E 0.0 6435 E 0.0 6509 E 0.0 (GLDD (c)92 1206A B1.30 7:53 AM 2) RECEIVED Alaska O# & Gas Co~s. Commission Anchorage ~E BAY DR NG TIE-IN i0050 7890 377! 42,82 END DROP ~ TURN 10853 G3~G 4838 37,89 TARGET ~485 8802 4805 37.89 TO 1~§38 9~8g 4885 37.89 ~2-06A VERTICAL SECTION VIEW Section at: S 53.42 E TVO Scale,: i inch = 300 feet gep Scale.: i inch = 300 feet Braun ..... : 05/20/92 £r~a~ Land £irectiona] OrJJJing 3800 3750 3900 4050 4200 4350 4500 4850 4800 4950 5~00 5G50 5400 5550 5700 Section Departure <- H/BON : HilIOS -> BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSi WP TRIPLE RAM STACK WORKO VER RISER ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE PI PE RAMS i PI PE RAMS I DRILLING SPOOL 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE i i . BLIND RAMS I I ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee ~'~ ~//~ ~/~-~ (2) Loc ~~ (3) Adm i n 2J$,'~-r [9 th u [10 & 13] [14 thru :22] [23 thru '28] . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company Lease $ Well YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~rnber appropriate .......................................... Does well have a unique name & n~rnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. I~ well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~oo~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... NO REMARKS (]6) Other ~'/~/ J/z?//~2_ [29 thru 31] (7) Contact ]]32] (8) Addl [~~ geology' DWU_ - engineer lng: /L -- Ml~ F/ LCSr7~'~']' BEW.~~3'~ ~-~ dH 5/$'~/'f rev 04/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL uNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,, J Additional 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. o?~ FiEbD NAME ~ P~UDN[)E BAY STAT~i : AL,~SKA APT w[J~,~ER : 50-029-~040!-0~ RECEIVED JUL 1 ~ 1992 Alaska Oil & Gas Cons. Commission Anchorage bis Ta¢~ 'Veriflcatlon L, istlr~q Schlumberger g!ask:a ComPutI~na Center 7-JU5-~992 06:0~ 8F~V!CE [~E : EDIT DAT~ : 92/07/ 7 O~IC!~ ~ ~LIC COMTINIIATI()~ # : CO~ENT : ARCO ALASKA, INC.,PR!!DF!OE BAY,I, 2-fA,500292040101 **** TAPE HEADER **** S~RVI'CE NA~E : EDIT DaT~ ~ q2/07/ 7 O~!G:I,N : WLIC COMTI~[JhTIgN # ~ ! PPEv!ouS TAPE : Cn~CNT : ARCF') ALASKa, I~/C.,PR(i[)HOE BgY,12-6A,50029204010~ TlPM ~EADER P~!IUHOE B~Y UNIT LOGGING COmPaNY: TAP~ CREATION [)ATE: JOB DATA 8~I~FAC~ LOCATIO~ SECTION: ~Sb: ~WL: K~]bI,Y BIJS~!NG~ GROHND LEV[~IL; 923~9 D. W A R bi E a K. MUDSON 12-6A 500292040101 ARCO A.[,ASKA, INC, SCHLUMBERGER WE~L SERVICES 6-JUL-9? 2ND STPIUG RUN 2 RUN 3 .!5E 579 7].00 7!.00 ()PEW [{f]l;E CASING DRILLERS ~IT S!ZF (IH) SIZ~ (IN) ngpT~4 (FT) ~,~2S 0.0 Verification bistincj 7-JUL-1992 06:02 Scblumberc~er Alaska. ComDtltinO Center 3RO STRING ST~ING [~UN ?~iU~iBER 1., ..)~IGIN~5 ~B HEIGHT OF 73' FOR T~OL ZERO STa~JD~.Rf) [~PEN 'HOLE DEPTH COMTROL, TOLL STRING (BOT-TOP): DLb-B.}4C-GR-!CC-Ak~$-SP, 19,200 PP~.~ C}4I.,O~IDES. P/kGE: **.** FILE 8ERV!Cg : FblC VFRSIC)N : 00~. ~07 DRTF : 92107/ 7 ?~.aX REC SIZE : FILE TYPE: : LO L~ST FILE : EDITED CURVE8 All tool str!.nqs: I) I:?pTH IMC~E~E~T FILE 8tl~%lPY PBU ~OOL CODF'i BASFL!NF I, OeDth 0.5000 sni~te~ and clipped curves; all runs merged; START Dt{PT~ ~!.6n3,0 STOP DEPTH !1.293,0 11~93,0 CI.JPVE FO~ $~{!F'TS: GP FT DATA (;'.!E.~%SURF. D DE~TH) .......... ~LJU!VAI, EqT 11671,0 11670,5 !!670.5 11670.5 11657.0 !.!652.5 11657.5 I~636.0 11635.5 ! !606.5 11607,5 11547.5 1154~.0 ~!470,0 11480.0 ~1a71.5 11471.5 ~!428.n 11426,5 ~1407.5 11406.0 ~!405.5 !1.40~.0 ~0 cased hole data. !.,iS Taoe Verlficatio~ Listt. nq Scblu,'~eroer AlasKa Co,~rJutinq Center 7-jOb-1992 06: O2 !136~.0 1.00.0 ~ERG~D D~TA SOURCE PBU TOOL CODE $ J1365.0 RE,ARKS: TNE DEPTS SHIFTS S~{O~N ABOVE REFLECTS DT TO GR AND LL~ TO GR (CARRYING LBD). T}IE SP WAS NOT S~IFT~D. I,!$ FORMAT BAT~ PAGE: ~ 66 0 3 73 40 ~ 66 5 66 6 73 7 65 ~ 68 0,5 q 65 !~ 66 25 12 68 !3 66 0 14 65 FT !5 66 6~ !6 6~ ! 0 66 0 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ** SET 'rYP~ - CHA~J ** NAMF S V ~I~J!T S~VlCF gP[ h T FI NttNR NtJM~ S . CE$S ....... . -. ~ .1 ~ .If) DRDER ~ I,~C TYPE ~LASS MrJD NI/~R SIMP F.!.,F.~ CODE (HEX) DF_PT FT 59050.:3 00 000 00 0 1 I 1 4 68 0000000000 DT BCS bs/g 5995(3.3 0O 000 O0 0 ! I 1. a 68 0000000000 G~ RCS G~PI 5q9503 O0 000 O0 0 ! 1 1 4 68 0000000000 TTNS nC8 !,g 5:,~: %03 O0 on0 . 0 O ! 1 ! 4 68 0000000000 T~:~D RCS Ltl ~':~o 5(11 O0 000 00 0 ! I I 4 68 0000000000 LL!) DLL (.)H~M 590503 O0 0,)() O0 0 t I ~ 4 6P 0000000000 LL~4 Dbb 0~{~ ~ 59~5n3 O0 OOn O0 0 1 1 1 4 68 OOOO000000 S~ DL, 5 ~.~V 59050~ O0 000 O0 0 ~. ! !. 4 6fl 0000000000 LIS Tao:e veriflcat~on I.!istl...pq 7-JUL-!992 06:02 Scblumber~er AlasKa Comput!n~ Ce,ret PAGE ID r~RDER ~ bO~,(' TYPE~ CLASS.~ ..........MOD ~U~!~ S~MP ELE~ CODE (HEX) "".. '~*~; ;"~,, .... ~,~:"~;"[;"'"~o.~ .... oo"'"""'"",'",'"','"'-'""'"---',,"","""-'"ooo oo ~ 4 .. . OooooooOo g~F]S Pl..,b [)H?q~ 59q503 O0 ()00 O0 0 ! ! ~ 4 68 0000000000 *'* DATA ** DEPT. 1175~ 0o0. .... DT.BCS :999,~50 GR,BCS -999.250 T~.EN~.BCS T~No,BCS 476:5P6 [~I.,D.DLL 09'9.250 LLU.DLI,, -999 250 SP DLL ~T~,DL[, -999°250 MR~S.[)I~L -999,250 DEPT, 11700 0n0 DT BCS 79,4.00 G:N.BCS -ggg 250 TENS BCS T~.~~,. ~':_' · . CS 594:242 bLD blt, 4 850 L!.~,DLL 6 706 SP:DLL DWPT. !!60o,000 DT' [%CS 91.200 (;R,BCS 38 762 TENS,BC8 TEND, BCS 659.989 [~[,D: D~ .[~ 7,671 LL~, [}bL 7:113 SP DL5 DFPT, 11293,000 DT,BC$ 106 750 GR.SCS 119 777 TENS,BCS M T E~. i) [..:, [., 179,75~ MPES.DLL 0,105 ....... ** ENl.) OF DATA 400O00 ~99: 2so 5935,000 -999,250 5990 6090,000 28,375 6270 ~00 ~9:: 5o 6155,000 20.250 SFRv!cE ~'~AX ~FC SIZE L~S? FILE rblC 00!a07 02/07/ 7 1024 LO I~., ~aDe r cat. o SchlumberQer AlasKa Comptltin~ Center 7-JUL-1992 06:02 PAGE: **** FI[.,~] HEADE~ **** FIhE NAmE : EDIT .002 $~RVICE : FLIC DaT~ : 92/07/ 7 ~AX ~C SIZE FIL~ TYPE : FIL~ Sadlerochit run mresented first (pri~na. ry depth control'strl,.nQ used to depth...ft t..e- Sadler interval) followed ~'~Y files ~or other main pass strln~$ per run. TOOL ST~ING P~,SS NUb'DER: 1 DEPTH INCR[~iMENT: 0.5000 F l I.,,E SU~iMARY VEN[>O~ TOOL COP~': S,.ART DEP_H X~[''''. ..... '''' '''''7;''''11709 ni',T, I .!732,0 !,OG i'{E~DER D~TA DATE !'.,OGLED: TI~E CIRC!.iI,,~TIDN ENDED: TD [~ILLER CF'T): TD LOGGE~ ( TOD ~,:]TT~ LF)GCT NG SP~]ED ( FP~-iR ) STOP DEPTH 293,0 !1293,0 ~HC F)!,,L Ob L $ TOOL STRING (TOP 'rft Rr~TT~?) VE,"iOO;? TOF)L CODF TOnL TYPE L[,I~RY , . c ..... ~tEAo. HOD. TEI,E'TTPY CART~ IDGE: {;.A:~A R~Y SONDE Bf}~!EHOLE SOrbIC CAPT. BORE~9I.,~ SO~,'IC SO~DE D!.ll[, [,A~I'EPOLO~ CakT, DUAL 6ATERObOG SONDE DUAL LAT~:ROLOG ~O~EHOL~; A,~F) CAST~.:G D~TA 25-dUN-92 5~0-325 230 25-J11~-92 1016 25-JUN-q2 11755 0 1174910 I!~90.0 1!.732.0 1~00.0 TCC-~ 32o S<;C-S~ 60 S!.,C-UA. 1 )6 SLS-WA 2001 D!,C-!) 96° DLS-F 975 D[,E-E 975 7-j[.I[,,- ! 992 06:02 500 982~.0 KCL POLY~E~ 9.60 !8,o0 ~,50 5.60 I~3.0 0,2..8 0,213 0,332 66.0 72.0 66.0 NEUTRON TOOL ~hTRI×: SANDSTD~E ~AT~IX DENSITY: 2.65 gObM CORRECTION (I~): TOOL STA~O[]FW ~ E ~4 A R K ..... ~' '.~ uRPTH CO!qTROL FRF)~ TH'~S ~EFEREN TOOt, ST~ING (BOW-TOP): DLL-B~C-G~-TCC-a~$-SP. LIS FO~AT DATA LIS ?a~e verification Llstino ~chlumberger Alas~.a Computino Center 7-JUL-19~ 06:0~ PAGE ** SET ......... ,aFl APl FIL~i ID r)RDE~ ~ b(:)G TYPE CL~.SS '''''''''''''''''''''''''''''''''''''''''''''FT 5995. 0 000 BMC US/F 599503 O0 000 Bf~C IlS 599503 00 000 BHC US 599503 O0 000 B~C US 599503 O0 000 BHC !!$ 599503 00 000 BlriC NV 599503 Off 000 BHC GAPI 599503 O0 000 B~C bB 599503 00 000 g~C D~GF 590503 OO 000 BHC [)H~ 599503 O0 O00 B~C bB 590503 00 000 DLT OHiqM 599503 O0 000 DLT OMMM 599503 O0 DbT ~V 590503 OO 000 DI,T GAP% 599503 O0 OOO DbT bB 590503 00 000 DLT DFGF 59950~ O0 OOO DLT Ogq~ 599503 O0 00O TYPE - CHAN ** NLt~B NUMB SIZE REP? PPOCESS S~!P ELEM CODE (HEX) ''''''''''''''''''''''''''''''''''''t 4 6~ 0 0 0 I ! 4 68 0000000000 O0 0 2 oo o ~ ~ ~ ~ ~ oooooooooo oo o ~ ~ ~ ~ ~ oooo~ooooo oo o ~ ~ ~ ~ ~ oooooooooo oo o ~ ~. ~ 4 6~ oooooooooo 00 0 2 ~ ~ 4 68 0000000000 oo o 2 ~ ~ 4 6~ oooooooooo oo o 2 ~ ~ ~ ~ oooooooooo oo o ~ ~ ~ ~ 6~ oooooooooo oo o ? ~ ~ 4 ~ oooooooooo oo o ~ ~ ~ 4 ~ oooooooooo oo o ~ ~ ~ 4 ~ oooooooooo O0 0 2 1 I 4 68 0000000000 00 0 2 ! 1 4 68 0000000000 oo o ~ ~ ~ 4 ~ oooooooooo oo o ~ ~ ~ ~ ~ oooooooooo oo o ~ ~ ~ ~ ~ oooooooooo oo o ~ ~. ~ ~ ~ oooooooooo D~-PT · TT].B~C TYqP.. DLT DFpT. TT 3, TF~:S. B,~C TFNS · O!..T DKPT. 11776,00o DT. !3HC 84,500 TT1.BHC 552 800 TT2,BHC 5~-9,209 TT4,B~C 3~9.200 SP,BHC 20:000 GP.BHC 1545,00o ~rFq.g~C 181 ,471 ~S, gH(] O, 100 HTEN,BHC 2.216 b!~L), t')bT 1.0.~7 SP.DLT -20.000 GR,DLT ~545,000 ~':~TE ~. r) ~,T 181.47l ~RKS, DLT 0.100 HT~;N,DLT 1.1.700,00o DT,q!IC 79.400 ~T1 ,BHC .525,600 TT2.BHC 530.000 TT4. [~[tC 372.400 SP.BwC 20.000 GR.BHC 5935 000 ~T~u I~HC lgl 1~ ,4RES,~C 0.100 HT~N,B~C 6.506 I.~I~ I.). D !.,T 5.lb0 SP, I)LT -20.000 a~.DbT 5935,009 i~!'r~:~, I)LT lal.3~ t~,aES. PI,T 0.1oo ~TEN,DbT 11600.000 DT.~aC 90.200 TT!.BHC 58~.000 TT2.BMC 5P6,0aO TT4,~HC 404.000 SP,BHC 2,750 GR,BHC 5900.000 ~r~.SgC 1.81.332 MRES.BHC O.101 HTEN,BHC 7.327 LLD,DI,T 7.2C5 SP.PbI 2.750 GR.DLT 384.800 39.238 -154,627 39.238 -154,627 368 800 25:940 594.242 25,940 594,242 401.600 38.762 658.989 38.762 LIS Tane Verl.ficat~.on Listinq 5chlu.m. bercler Alaska. ComputtDq Center TEb~S . D!.~T 599©.0©0 NTEF~. D!.,,T DEDT 1 !.500,1200 DT BHC TFMS. BI'lC 6090.000 LbS. DLT ~. 071 TEK~.DbT 6090.000 t)EPT. !. 1 400.000 DT.BHC ~C 4'~.400 TT~ BHC ~HC 627o, 000 T, LS.DLT 466.8gO LLO,DLT TE~!S.DLT 6270.000 DEPT. 11290. 000 TDT', .... TT3, B~:C 666. 400 y :,pT 4. BHC TENS. gHC 6095,000 .E~, BHC LBS, Di..,T ~, 41. 3 bLD. DLT TF-~S. DLT 6095,000 ~'rEq. DLT **** FT[,E T~AILER **** FTLE NA~E ! ~DIT .002 SF.~VICE : WLIC V E'~glON : 00~ a07 D~T~ : 92107/ 7 ~.~X R~TC FILE TY~E L~ST FILE : **** FII,E 1-4 ~: a'[) E ~ **** FTLF NA'~,E : EDIT .003 S~RVlC~ : WLTC V~R$ I, C},q : 00 .~. A07 I.)~T~ : 92~07~ 7 ~aX PEC SIZr : ]024 7-JOL-! 992 06:02 181.332 ~RES.DLT 89,900 ~Ti .~%HC 406.8()0 SiP. BHC !81.661 8,0~0 8P. BLT 18 i. 661 MRE8, 60.400 TTI,aHC 307.200 SP.HHC IS0,865 ~RES,BHC 30!,969 SP.DLT !80,865 MRES.DLT I(i)4.900 TT1 .BHC 454.000 SP. B!.,~C !.78.758 t4RE$.:BHC 0 28~ 8P,DLT 178:758 M~E$.DbT !.06,750 454'400 170 6~2 0:234 SP.DLT 1.78.6~2 mRE~ OI,T .... 0.101 580.80O 28 375 o :1o 28 375 427.600 19 750 0i102 19 750 0 1.02 661.200 2~,75() .105 21750 0:t05 665,600 30.438 0.105 30 438 MTEN.DLT T~2 OHC ~R:BHC H?EN'BH~ GR. DL? TT2.BHC GR.~H'C HTEN.BHC GR.DLT HTEM,DbT TT2 BHC GR:BHC HTEN. BHC GR. DbT HTEN,DbT TT2,BHC GR, BHC MTEM.BMC GR, DbT HT [':'N . DLT PAGE: 658,989 4041,000 ~0'~79 678,482 30879 678:482 306.800 57'921 77:2'674 57'9~X 772,674 448 400 118 840 703 389 118 840 703 389 464°000 107,284 721,048 721,048 LIS Tare verification Listin~ Schlu~berqer A!askla ComDutin~ Center 7-JUb-199~ 06:0~ PAGE: Curves and loq nearer data ~or each pass, tool str~n~, and run in s~parate TOO[ STPING NU~BER: DEPTH INC~E~EMT: 0.5000 VE~DOR TgOL CODE START DEPTH ~NC $ ' L~G HEA~ER ! 11590.0 TI~E CIRCULATION E~DED: TI~E L[}GGER Q~ BOTTC}~: WD nRILI,~R (FTC: TD ~GGgR(FT): TOP [,0G INTERVAL CFT): EOTTO~ I,[IG I~TERVAb (FT): LOGGT~G SPEED (FPiqR)! STOP DEPTN 11293,0 11293,0 STRING (TOP TO BOTTOM) VEDDOR TOOL CODE TOOU TYPE GR Pbb !) [, L DLL AI~X Ib!...~I ARY ~EA8, :¥EbE~,~MTRY CARTRIDGE GA~q~A RAY SONDE BORENObE $Ot4!C CART. B~REHOLE MO~'!C SU~DE DJ.IA!, LATEROL['IG CART. D{tA!, I,AT~ROI.,,[]G SONDE DUAL bATERO[,:OG DPlLI,MRS CASING DEPTi.~ (FT)~ LOGGERS CASI:.~G DFPTH (FT): ~ORENOLM COND ! TIOt,JS ~4UD TYPF: 'al~ VISCOSITY (S) ~ FLUID LOSS (C3): ~5XIUl.]~ RECORDED TF~t.'!PERATURE (DFGF) RESISTIVITY (OH~?~) AT TEHPE~ATURE (DEGF): ~flI][';. AT MEASURED TE~DERAT~RE uur) AT ~tflTTO~ NtiLE TENPERATtJRE ~UD FILTRATE AT ~,~1.39 P'TLTPATE AT (~HT): 25-jUN-92 5B0-325 230 t0!6 11755.0 11749.0 !.1290.0 I!.732,0 1800.0 25-dUN-92 25-JUN-92 TOOL ~U~BER TCC-B 320 SGC-$A 60 SLC-UA 136 SI,S-wA 2001 D!,,C-D 969 DL$-F 975 DLM-E 975 ~,500 98~2.0 KC[, POLYMER 9.60 !~.00 ~.50 5.60 1~3.0 0,298 66.0 0.2J, 3 72.0 LIS TSoe verifi, cation Listing. Sc~lumberqer AlasKa Computinq Center 7-.JUL-!992 06:02 CAKE AT (BHT~I O,332 66.0 TYPE {EPITHERMAb Oa THgP~Ab): NATRIX: ~ATRIX DENSITY: CO~RFCTION (IS)~ SANDSTONE ~.65 TOOL STAHDOFF (I~'."): USED STA~:~DARD OPE~ HObF: DEPTH CONTROL FRO~ T:[qlS REFEREN Tf3qL STRING (~.OT-T(}P): D[~L-BHC-GR-TCC-A~S-SP. S LIS FORe, AT DATA PAGE: 10 ** PAT./% ?C]R'aAT SPECIFICATION RECORD ** SET TYPE ,! 6 6. ~ 66 3 73 ~0 4 66 5 66 6 73 7 65 n 68 0.5 9 65 FT 1! 66 !,2 1~ 13 66 0 15 66 68 !6 66 1 0 66 1 IT) ORD~iR ~ i~nG TYPE CLASS Mr!O NtJ~ SA~P EBE~,~ CODE (HEX) DFPT FT 590503 nO 000 O0 ~ 3 1 1 4 68 0000000000 ~T BHR tlS/F 599593 0() 0OO O¢) 0 3 1. 1 4 68 0000000000 TT1 BHR US 59q503 O0 On,~ O0 0 3 ! ! 4 68 O00000000O TT2 BUR ils 5qo503 O0 OOO OO 0 3 ~ 1 4 6~ OOOO000000 TT3 ~%H~ t~S 59Q503 O0 9o0 O0 0 3 1 ! 4 6A 0000000000 LIS Tare Ver:{.fication !,ist.inq Schlumhoroer A!.asKa Comput~nfl C nter 7-Jt,lt,-1~92 06:02 PAGE: IJ ~,. SE 'IT , V SP BHP ~V 59q503 G~ BHR GAPI 599503 00 TENS ~RR LB 599503 00 ~TE~ BNR DEGF 599503 O0 ~RES B~R OH~ 599503 00 HTE~ B~R b~ 599503 O0 !,LS Db~ OH~ 59~503 00 t.,LD DbR OH~ 599503 O0 S~ DbR aY 599503 O0 G~ DLR GAPI 599503 O0 T~$ Db~ bB 599503 00 ~TE~ DLR DEGF 599503 00 ~RES DbR [)N~ 599503 0~ HTE~ DL~ LB 5995013 O0 R # bOG TYPE CLASS ~Ob NU~P, ' $.~P ghee! C 0 1 4 000 00 0 t 1 I 4 000 O0 0 3 I 1 4 000 00 0 3 1 I 4 000 00 0 I ! I 4 000 O0 0 3 1 1 4 000 00 0 3 1 ! 4 000 00 0 3 1 I 4 000 00 0 3 ! 1 4 000 00 0 3 ! I 4 000 00 0 3 ! t 4 000 00 0 3 ! I 4 000 O0 O 3 ! t 4 O00 00 0 3 1 I 4 000 00 0 3 1 t 4 g ..... ,S$ ODE [HEX) ooOoo0oo 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 6~ 0000000000 68 0000000000 68 000000000O 68 0000000000 ,, n ~ T A , * DEPT, t i 029. 000 I)T. TT3, ~ t-'~ R 595. 600 i!~T4 [..,I.~ fObt~ 7. 909 TE~,~S: Dl.:,a !705,000 MTEq, t P T. ! !. 600.00 () P ?. TT3, BHR 595,600 TT4. TF~S, ~%i:qR 5a30,00n . ,-., . . -, ~'! .... ~ LbS. DLR 6,734 LLD, TENS.Df,D 5~30,000 DEDT, 1 ! 5oo, ooo r~T, TT~.BNR 581,200 TT4. TENS,BHR 6155.000 ~:CE~i'. I.[,8. n t, r',' 7. 805 LI, L). TWNS. O[,R A 165,000 ~'~TE~. DFPT. 11400. 000 DT. TT3. BH~ 427. 600 TT4. TENS.RNR 6250.000 L[.,?,. DLR 50 3.4 4P TFNS. DI_,R ~250. 000 q'i' F',~. DEPT. 11300.000 PT. TT].BHP 667.20~ TT4. I,bS.OL~ 1.971 LI.,D. TE~!S.t)I,R 6125.000 ~rEa. BHR 9 R P R 40 B~R 18 DLR D 5 R 18 a~4R 9 ~ H r~ 40 [)DR 18 D !J ~ Db~ DLR B~. R 'aHR r)bR DT.,~ 5.400 TT1.BHR 4.400 SP.BER 0.700 ~RES.BHR 6,750 SP.DbR 0.700 ~RES.[L.R 5,400 TTI,BH~ 4,400 8P,BH~ 0,700 ~RE$,BMR 5,792 SP,DLR 0,700 NRES.gLR 89,300 TTI.B"R 4o4.~00 SP,BHR 179.934 MRES.B~R 7 734 SP,DbP 179:934 MREiS.ObR 59.600 TTI.B~R 310.4U0 SP,BHR !B0.071 ~PES.BHR 33!,85R SP,!)LR 180.07! 104. 300 TTI, 44.9 600 0 317 SD. D[,R 17R:733 ~,I~ES.!)LR 610.400 TT2.BMR -20 000 GR.BHR ' . ~ .10l HTEN.BHR -20,000 GR,DLR 0.101 HTEN,DbR 6!.0,400 TT2,BHR -20,000 GR,BHR 0,101 HTE~, -20. 000 GR. DI..,R 0. I 01 HTEPJ. DLR 579.600 TT2.BHR -20.563 GR.BHR 0.I01 HTEN.BHR -28.563 GR.DLR 0,101 HT~N,DLR 426.400 TT2.BHR -16,688 GR.BHR 0. 103 HTEN.RH~ -16 6On cr.~br 01103 HT~N.DL~ 664.R00 TT2.BHR -22.625 GR.B~P 0.105 HTEN.BHR -22,625 GP,DLP 0.!05 HTEN,DLR 420.000 39 238 385:~771 39 238 385 771 420,000 39.238 644.3!7 39 238 644~317 402,800 30,769 667,938 30,769 667,938 307.200 57,244 780,462 57.244 780.462 454.000 1t3.948 686.695 113.948 686,695 LIS TaLe Verl. flcation Listl.n~ Sch!umber~er hlaska ComDuti~o Center 7-JUb-~99~ 06:02 PAGE: 12 TE~S.BgR 6035.009 ~TE~.~ 178.243 ~ES.B~IR LLS.DL~ 2,0~9 ULD.OLR 0.305 SP,DLR TFNS,OLR 6035.000 ~TEg. DL~ i78.243 ~RES.DLR -999 250 TT2.BHR O, 106 HTEN.BH.R 0.106 -999. 250 !21,132 7~i..!10 12:1.132 72!, I l 0 ** EMD O~ DATA ** **** ~!LE TRAILER **** FILE ~!AME : EDIT VERSIO~ : 00~.a07 DAT~ : 92/07/ ~aX ~C $IZ~ : !024 FIL~ TYPE : LO L~ST FILE : **** T~PE TRAt[,ER **** DaTE ~ 92/07/ 7 O~I~IN : FL'lC TAPE NA~E ~ 92389 P~VIOUM T&PE : CO~E~T ~ ARC(]} AI,ASKA, INC.,PRUDNOE BAY,12-6A,50029~04010~ **** REEL TRA!LMR **** DaTV : 92/07/ ? O~!CIN : ~LTC RFEI~ MA!~E : 9238~ CO~TI~UATI(.)~ ~ : CO~U~NT : ARC/] ~!.,ASKA, INC.,P~!!PHOE gaY,~2-6A,500202n40101
