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Home My WebLink About200-106 ! " # " $ %& ' ()! * '$ +, !- ."!! /, +, 01021*-1 3+ - " ' $ 0/04 (.254 *(/4 /*504 % $ (.254 20/4 7 + 9:: -5#30; ,#.1 /*/46$ 7$ < 7+ ': - /246$ /20.46$ /(8146$ !3 (/8247$ (/5547$ *1147$ !3 0 =9 ' ) + - 8 = 2" < $ ' " %& ' $ , ' (" < > "$, % $ > >)!? @ ,@> '!!3 %& ! % 9 04 08.(4 *80411(24*; ?< A01*1#510846$ 21 2.B > 0 %6!%+ - .14 0*214 ) (; /#23.; , 11814 %,C ,C),!$>!% 7)!66))! !""#$"%#" &"#$"'#!"'((#""#"" ) 2 $ !0 ! ! 5" D"< ""!&&&* ++,) <:) D&118(1 :C//21 8 $#(' < $ ' )E $ FFF F 5 += 01021*1:021*:G020.8- F > #6 - 04 0*.(4 F . '!!#""& % > % 9! $ $ ")!?"> F " #D #D *)' ' '< F A +/1*-(*1#515 ") ) '% <" % < <" % < <D<2#8< 7! 1#515 13010 " 81' 6 Hole at 11(2#0/04 Hole at *80#*(/4 By Meredith Guhl at 10:19 am, Feb 16, 2022 Travis T. Smith Digitally signed by Travis T. Smith Date: 2022.02.16 10:11:57 -09'00' RBDMS SJC 021722 DSR-2/16/22 ! " # " $% & $ " '(')* +,' -((./0,12'/.*3,)4 Page 1/1 CD1-43 Report Printed: 2/9/2022 Cement Cement Details Description Cement Squeeze Cementing Start Date Cementing End Date Wellbore Name Comment OPEN OA, 1300 PSI, ONLINE LRS WITH 10 BBLS NEAT METHANOL DIESEL DOWN OA AND 85 BBLS OF 80 DEGF SW WATER. SWAP TO SLB CEMENT PUMPER COME ONLINE WITH 5 BBLS FRESH WATER SPACER FOLLOWED BY 20 BBLS NEAT 15.8 CLASS G, THEN 15 BBLS CLASS G WITH 2 PPB CEMNET, SWAP FOLLOW WITH 15 MORE BBLS OF NEAT CLASS G. CHASE WITH 5 BBLS 2% CRW CI FRESH WATER. SWAB BACK TO LRS AND PUMP DIESEL DISPACEMENT. WHEN CEMET HITS SHOE, SLOW RATE BACK TO 1 BPM PUMPING AWAY AT 1000 PSI, SLOWLY WORKS UP TO 1110 PSI. AFTER 10 BBLS AWAY, COME OFF PUMPS AND PRESSURE DROPS TO 950 PSI. WAIT 15 MINUTES AND START SQUEEZING ANOTHE 10 BBLS INTO SHOE, SPOTTING CEMNET AT SHOE. KEEP 1250 PSI TRAPPED ON OA. (CEMENT REPORT IN ATTACHMENTS) Cement Stages Stage # 1 Description Squeeze – Formation Squeeze Objective Top Depth (ftKB) 2,070.3 Bottom Depth (ftKB) 4,023.4 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment OA Cement Shoe Cement Fluids & Additives Fluid Fluid Type OA Cement Shoe Fluid Description Estimated Top (ftKB) 2,070.0 Est Btm (ftKB) 4,033.0 Amount (sacks) Class G Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 6.00 CmprStr 1 (psi) 2,000.0 Additives Additive Type Concentration Conc Unit label Cement Squeeze Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 7/16/2008 CD1-43 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: WRDP pulled, EVO TREIVE set, OA Cement sqz input 2/8/2022 CD1-43 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.70 Top (ftKB) 36.4 Set Depth (ftKB) 2,786.1 Set Depth (TVD) … 2,385.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC-MOD Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.6 Set Depth (ftKB) 10,065.1 Set Depth (TVD) … 7,131.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) Top (ftKB) 10,065.0 Set Depth (ftKB) 12,921.0 Set Depth (TVD) … Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.6 Set Depth (ft… 9,718.6 Set Depth (TVD) (… 7,044.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 32.6 32.6 0.00 HANGER 4.500 10.000 FMC TUBING HANGER 1,836.8 1,712.5 41.16 NIPPLE 3.812 6.062 CAMCO BAL-O NIPPLE 4,216.2 3,401.6 44.36 GAS LIFT 3.938 5.200 CAMCO KBG-2 6,827.1 5,201.8 50.83 GAS LIFT 3.938 5.200 CAMCO KBG-2 9,520.4 6,940.3 54.62 GAS LIFT 3.938 5.200 CAMCO KBG-2 9,578.0 6,973.0 56.43 NIPPLE 3.813 5.000 HES 'X' NIPPLE 9,630.0 7,001.0 58.52 PACKER 3.875 5.970 BAKER 5-3 PACKER 9,706.5 7,038.7 62.77 NIPPLE 3.725 5.000 HES 'XN' NIPPLE 9,717.4 7,043.6 63.43 WLEG 4.500 5.000 WIRELINE ENTRY GUIDE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,854.0 5,218.8 50.86 PLUG 4.5" EVO TREIVE ST 1/19/2022 0.000 9,511.1 6,934.9 54.40 PACKER 3.74" UPPER WEATHERFORD ER PACKER 6/28/2015 2.375 9,514.9 6,937.2 54.49 SPACER PIPE 4' SPACER PIPE - PATCH 6/28/2015 2.441 9,518.9 6,939.5 54.59 CROSS OVER ECCENTRIC CROSSOVER, WILL NOT PASS TOOLS 6/28/2015 1.500 9,526.6 6,943.9 54.77 CROSS OVER ECCENTRIC CROSSOVER, 1.50" ID will not pass tools 6/28/2015 1.500 9,527.3 6,944.3 54.78 SNAP LATCH WEATHERFORD SNAP LATCH 4,400 LBS TO RELEASE 6/28/2015 2.250 9,528.2 6,944.8 54.81 PACKER 3.74" LOWER WEATHERFORD ER PACKER 4/27/2015 2.375 9,742.0 7,054.3 65.03 FISH 3.81" CAT SV DROPPED IN HOLE 3/3/2015 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,216.2 3,401.6 44.36 1 GAS LIFT GLV BK 0.188 1,908.0 7/29/2016 2 6,827.1 5,201.8 50.83 1 GAS LIFT GLV BK 0.188 1,848.0 7/28/2016 3 9,520.4 6,940.3 54.62 1 GAS LIFT OPEN 4/2/2015 Notes: General & Safety End Date Annotation 12/14/2014 NOTE: Unable to determine mandrel orientation at GLM 3 12/14/2014 NOTE: TUBING LEAK ID AT 9520"RKB'. 1/11/2014 NOTE: Mandrel Orientation: 1) 5:30 2) 6:00 3) 9:30 CD1-43, 2/14/2022 1:43:45 PM Vertical schematic (actual) OPEN HOLE; 10,065.0-12,921.0 PRODUCTION; 34.6-10,065.1 FISH; 9,742.0 NIPPLE; 9,706.5 PACKER; 9,630.0 NIPPLE; 9,578.0 PACKER; 9,528.2 SNAP LATCH; 9,527.3 CROSS OVER ; 9,526.6 GAS LIFT; 9,520.4 CROSS OVER; 9,518.9 SPACER PIPE; 9,514.9 PACKER; 9,511.1 PLUG; 6,854.0 GAS LIFT; 6,827.1 GAS LIFT; 4,216.2 SURFACE; 36.4-2,786.1 NIPPLE; 1,836.8 CONDUCTOR; 41.0-121.0 HANGER; 32.6 PROD KB-Grd (ft) 39.34 Rig Release Date 8/30/2000 CD1-43 ... TD Act Btm (ftKB) 12,921.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032034400 Wellbore Status PROD Max Angle & MD Incl (°) 90.41 MD (ftKB) 11,316.04 WELLNAME WELLBORECD1-43 Annotation Last WO: End DateH2S (ppm) DateComment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y Meredith Guhl at 4:03 pm, Jan 07, 2022 Travis T. Smith Digitally signed by Travis T. Smith Date: 2022.01.07 15:58:57 -09'00' '6597/ ; ; '/% dts 1/11/2022 JLC 1/11/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.11 15:13:18 -09'00' RBDMS HEW 1/12/2022 ϭͲϰϯKĞŵĞŶƚ^ŚŽĞKǀĞƌǀŝĞǁ WĂŐĞϭ ĂƚĞ͗ :ĂŶƵĂƌǇϳ͕ϮϬϮϮ ^ƵďũĞĐƚ͗ ϭͲϰϯKĞŵĞŶƚ^ŚŽĞKǀĞƌǀŝĞǁ WƌĞƉĂƌĞĚǇ͗dƌĂǀŝƐ^ŵŝƚŚ͕ϲϳϬͲϰϬϭϰ KďũĞĐƚŝǀĞ ZhϭͲϰϯ;WdηϮϬϬͲϭϬϲͲϬͿŝƐĂƉƌŽĚƵĐĞƌƚŚĂƚǁĂƐŽƌŝŐŝŶĂůůǇĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶϮϬϬϬ͘ dŚĞǁĞůůŝƐĐƵƌƌĞŶƚůǇƐŚƵƚͲŝŶĨŽƌƌĞƐĞƌǀŽŝƌŵĂŶĂŐĞŵĞŶƚĚƵĞƚŽŚŝŐŚǁĂƚĞƌĐƵƚ͘ tŝƚŚƚŚĞƵƉĐŽŵŝŶŐĚƌŝůůŝŶŐŽĨƉƌŽƉŽƐĞĚĚŝƐƉŽƐĂůǁĞůůtͲϬϯŽƵƌŝŶƚĞŶƚŝƐƚŽƐĞĐƵƌĞĂŶĚďůĞĞĚ ƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞŽĨĨŶĞĂƌďǇǁĞůůƐ͕ŝŶĐůƵĚŝŶŐϭͲϰϯ͘dŽĨĂĐŝůŝƚĂƚĞďůĞĞĚŝŶŐƚŚĞƉƌĞƐƐƵƌĞĨƌŽŵ ƚŚĞKǁĞƉƌŽƉŽƐĞƉƵŵƉŝŶŐĂĐĞŵĞŶƚƐŚŽĞŝŶϭͲϰϯ͘ KǀĞƌǀŝĞǁ^ƚĞƉƐ ϭ͘sĞƌŝĨǇϭϬͲϰϬϯ^ƵŶĚƌǇĨŽƌŵŚĂƐďĞĞŶĂƉƉƌŽǀĞĚĨŽƌKĐĞŵĞŶƚƐŚŽĞ͘ Ϯ͘DŽǀĞŝŶĐĞŵĞŶƚƉƵŵƉŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚƌŝŐƵƉƚŽƚŚĞK;ϳ͟ǆϵͲϱͬϴ͟ĂŶŶƵůƵƐͿ͘ ϯ͘&ůƵƐŚKĂŶĚĨŽůůŽǁŝŵŵĞĚŝĂƚĞůǇǁŝƚŚĐĞŵĞŶƚĚĞƐŝŐŶƚŽƉůĂĐĞĂƉƉƌŽǆŝŵĂƚĞůǇϭ͕ϬϬϬĨŽŽƚ ůŝŶĞĂƌĐĞŵĞŶƚƐŚŽĞŝŶƚŚĞK͘ŝƐƉůĂĐĞƚŚĞĐĞŵĞŶƚǁŝƚŚƐƉĂĐĞƌƉŝůůĂŶĚĚŝĞƐĞůŽƌĚĞĂĚ ĐƌƵĚĞĨŽƌĨƌĞĞǌĞƉƌŽƚĞĐƚŝŽŶ͘ ϰ͘ĨƚĞƌƚŚĞĐĞŵĞŶƚĐƵƌĞƐ͕ƉĞƌĨŽƌŵKĚƌĂǁĚŽǁŶƚĞƐƚ͘ ϱ͘ZĞƉŽƌƚǁĞůůǁŽƌŬƚŽK'ŽŶϭϬͲϰϬϰĨŽƌŵ͘ /DVW7DJ $QQRWDWLRQ 'HSWKIW.% (QG'DWH :HOOERUH /DVW0RG%\ /DVW7DJ &' OPRVERU /DVW5HY5HDVRQ $QQRWDWLRQ (QG'DWH :HOOERUH /DVW0RG%\ 5HY5HDVRQ&255(&7:5'3,'(5525 &' SSURYHQ &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH + 7RS7KUHDG :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH - 7RS7KUHDG %7&02' &DVLQJ'HVFULSWLRQ 352'8&7,21 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH / 7RS7KUHDG %7&0 &DVLQJ'HVFULSWLRQ 23(1+2/( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO«*UDGH 7RS7KUHDG 7XELQJ6WULQJV 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'«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dŚĞĚƌŝůůŝŶŐŽĨtͲϬϯǁŝůůďĞƌĞůĂƚŝǀĞůǇŶĞĂƌďǇƚŚĞϭͲϰϯǁĞůůďŽƌĞŝŶƚŚĞŶĞĂƌͲƐƵƌĨĂĐĞ͕ĂŶĚǁĞŝŶƚĞŶĚƚŽƐĞĐƵƌĞƚŚĞǁĞůů ĂŶĚďůĞĞĚƚŚĞĂŶŶƵůŝƚŽǌĞƌŽŽƵƚŽĨĂŶĂďƵŶĚĂŶĐĞŽĨĐĂƵƚŝŽŶƌĞŐĂƌĚŝŶŐĐůŽƐĞͲĂƉƉƌŽĂĐŚ͘ ϭͲϰϯǁĂƐĐŽŶƐƚƌƵĐƚĞĚǁŝƚŚĂŶŽƉĞŶKƐŚŽĞĂŶĚƚŚĞƉƌĞƐƐƵƌĞŽŶƚŚĞKǁŝůůŶŽƚďůĞĞĚĂůůƚŚĞǁĂǇƚŽǌĞƌŽǁŝƚŚŽƵƚ ƐĞĂůŝŶŐƚŚŝƐŽƉĞŶƐŚŽĞ͘dŚĞKŵĂŝŶƚĂŝŶƐĂƉƌĞƐƐƵƌĞŐĞŶĞƌĂůůǇŝŶƚŚĞϯϬϬͲϴϬϬƉƐŝƌĂŶŐĞŝŶƌĞĐĞŶƚŚŝƐƚŽƌǇ͘dŚĞd/KƚƌĞŶĚƐ ƐŚŽǁĚŝĨĨĞƌĞŶƚŝĂůďĞƚǁĞĞŶƚŚĞ/ĂŶĚKĚƵƌŝŶŐƚŚŝƐƚŝŵĞ͕ĐŽŶĨŝƌŵŝŶŐƚŚĂƚƚŚĞƐĞĂƌĞŶŽƚŝŶĐŽŵŵƵŶŝĐĂƚŝŽŶ͘ dŚĂŶŬƐ͕ dƌĂǀŝƐ &ƌŽŵ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂǇ͕:ĂŶƵĂƌǇϭϬ͕ϮϬϮϮϰ͗ϬϭWD dŽ͗^ŵŝƚŚ͕dƌĂǀŝƐdфdƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁ZhϭͲϰϯ;WdϮϬϬͲϭϬϲ͕^ƵŶĚƌǇϯϮϮͲϬϬϱͿĞŵĞŶƚKƐŚŽĞ CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. dƌĂǀŝƐ͕ tŚĂƚŝƐƚŚĞKƉƌĞƐƐƵƌĞŚŝƐƚŽƌǇ͍ǆƉůĂŝŶǁŚǇƚŚĞKƐŚŽĞƐŚŽƵůĚďĞĐĞŵĞŶƚĞĚǁŝƚŚƚŚĞĚƌŝůůŝŶŐŽĨtͲϬϯ͘ sŝĐƚŽƌŝĂ Victoria Loepp 6HQLRU3HWUROHXP(QJLQHHU 6WDWHRI$ODVND 2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ :WK$YH $QFKRUDJH$. :RUN 9LFWRULD/RHSS#DODVNDJRY CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 200-106 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20344-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559 CRU CD1-43 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 12921 feet Plugs measured None feet true vertical 7169 feet Junk measured 9742 feet Effective Depth measured12921 feet Packer measured 9630 feet true vertical 7169 feet true vertical 7001 feet Casing Length Size MD TVD Burst Collapse Structural Na t 0 Conductor 80' 16" 121' 121' 0- QE�' Surface 2750' 9.625" 2786' 2386' �� Intermediate Production 10031' 7" 10065' 7132' RECEIVED Liner JUN 14 2016 Perforation depth Measured Depth: Open Hole Completion, 10065'- 12921' MD (� (� True Vertical Depth: 7132'-7169'TVD AOGCom/ Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 9719' MD, 7044'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3, 9630' MD, 7001'TVD SSSV: WRDP-2, 1837' MD, 1713'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10065'- 12921' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 204 282 1130 1099 162 Subsequent to operation: 223 251 1056 1041 165 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kerry Freedman Email Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature /'J:1t7 iltkzei"------- Phone 265-6579 Date 6 ft 31(1, Vrl_ 7--/ /1(.... Form Form 10-404 Revised 5/2015 ,4 7%.2• 6' RBDMS L V Ju 4 20 6 Submit Original Only • • CD1-43 Scale Inhibition Treatment 5/15/2016 Aqueous Scale Inhibitor Squeeze Job pumped 5/15/16 from 07:30 to 10:30 hrs. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA-275/1020/900 - LRS pumped 8.5 bbls WAW5206 at .25 bpm while ACF pumped 85 bbls seawater at .55—2.25 bpm, preflush stage,TBG/IA/OA-900/904/840 - Job shut down to evaluate injection pressure response Interval treated: 10,065'—12,921' MD WNS PROD • CD1-43 ConocoPhillips "' Well Attributes Max Angle&MD TD F, , Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc. (rtxr,ilirp,a} 501032034400 ALPINE PROD 90.41 11,316.04 12,921.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD1-43,9/8/20153:07.25 PM SSSV: Last WO: 43.52 8/30/2000 - Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 9,911.0 7/16/2008 Rev Reason:SET WRDP-2 lehalif 9/8/2015 CasinStnn s HANGER,32.6 Casing Description g OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED ' r g Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread El ( . fis SURFACE 95/8 8.697 36.4 2,786.1 2,385.9 36.00 J-55 BTC-MOD NI : Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(N ..D). Wt/Len(I... Len Grade Top Thread ' 1 PRODUCTION 7 6.276 34.6 10,065.1 7,131.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread M 'lt, _-- OPEN HOLE 6 1/8 10,065.0 12,921.0 Tubing Strings CONDUCTOR 41.0.121.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/rt) Grade Top Connection TUBING 4 1/2 3.958 32.6 9,718.6 7,044.1 12.60 L-80 IBTM Completion Details NIPPLE,1,8368 a Nominal ID VALVE 1.8370 - Top(ftKB) Top(ND)(ftKB) Top 1=1(.1 Item Des Com (in) 32.6 32.6 0.00 HANGER FMC TUBING HANGER 4.500 1,836.8 1,712.5 41.16'NIPPLE CAMCO BAL-O NIPPLE 3.812 9,578.0 6,973.0 56.43 NIPPLE HES'X'NIPPLE 3.813 9,630.0 7,001.0 58.52 PACKER BAKER 5-3 PACKER 3.875 9,706.5 7,038.7 62.77 NIPPLE HES'XN'NIPPLE 3.725 9,717.4 7,043.6 63.43 WLEG WIRELINE ENTRY GUIDE 4.500 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE,36.4-2,786.1 Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 1,837.0 1,712.6 41.16 VALVE SET WRDP-2(SN:HRS-279)WITH DB LOCK AND 7/11/2015 2.125 3.94"PKG GAS LIFT 4,216.2 - 9,511.1 6,934.9 54.40 PACKER 3.74"UPPER WEATHERFORD ER PACKER 6/28/2015 2.375 9,514.9 6,937.2 54.49 SPACER 4'SPACER PIPE-PATCH 6/28/2015 2.441 PIPE 9,518.9 6,939.5 54.59 CROSS ECCENTRIC CROSSOVER,WILL NOT PASS 6/28/2015 1.500 OVER TOOLS 9,519.7 6,939.9 54.60 MANDREL 2-1/16"GLM w/1"OV,1/4"PORT 6/28/2015 1.900 GAS LIFT;6,8271 11 9,526.6 6,943.9 54.77 CROSS ECCENTRIC CROSSOVER,1.50"ID will not pass 6/2812015 1.500 OVER tools 9,527.3 6,944.3 54.78 SNAP LATCH WEATHERFORD SNAP LATCH 4,400 LBS TO 6/28/2015 2.250 RELEASE 9,528.2 6,944.8 54.81 PACKER 3.74"LOWER WEATHERFORD ER PACKER 4/27/2015 2.375 - 9,742.0 7,054.3 65.03 FISH 3.81"CAT SV DROPPED IN HOLE 3/3/2015 PACKER 9,511.1 , Stimulations&Treatments Min Top Max Btm SPACER PIPE;9.514.9 [ [E Depth Depth Top(ND) Btm(ND) CROSS OVER;9.518.9 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,065.0 12,920.0 7,131.8 7,169.2 FRAC 4/6/2007 ALPINE SAND FRAC TREATMENT,PLACED g 307,0006 16/20 CARBITE INTO OPEN HOLE,IPPA y6 ON FORMATION MANDREL;9,519.6, 10,065.0 12,920.0 7,131.8 7,169.2 REFRAC 4/23/2014 ALPINE SAND FRAC TREATMENT,PLACED GAS LIFT;9,520.4 _ 200,4606 16/20 CARBITE INTO OPEN HOLE,8PPA CROSS OVER;9,526 6 ON FORMATION id Mandrel Inserts ah SNAP LATCH;9,527.3 t t`.4 on Top(ND) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com PACKER',9,5282 t 1 4,216.2 3,401.6 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 2,066.0 6/29/2015 6:00 2 6,827.1 5,201.8 CAMCO KBG-2 1 GAS LIFT GLV BK 0188 1,901.0 6/29/2015 11:30 3 9,520.4 6,940.3 CAMCO KBG-2 1 GAS LIFT OPEN 4/2/2015 Notes:General&Safety IMP End Date Annotation NIPPLE,9,578.0 ° 5/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1/11/2014 NOTE: Mandrel Orientation: 1)5:30 2)6:00 3)9:30 f: 12/14/2014 NOTE.Unable to determine mandrel orientation at GLM 3 12/14/2014 NOTE:TUBING LEAK ID AT 9520"RKB'. PACKER 9,630.0 t NIPPLE;9,7065 n WLEG,9717.4 l FISH,9,742.0 PRODUCTION,34.6-10065.1 #k 4 i I. REFRAC',10,065.0 FRAC,10,065.0 ''`s" �a is I• OPEN HOLE;10,065.0-12.921.0 ' ', ' STATE OF ALASKA i. _3KA OIL AND GAS CONSERVATION COL,._.SSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate Alter Casing P r r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Tubing patch rq 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 200-106 3.Address. 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 i 50-103-20344-00 7 Property Designation(Lease Number)• 8.Well Name and Number: ADL0025559 CRU CD1-43 9 Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s): N/A Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary. Total Depth measured 12921 feet Plugs(measured) None true vertical 7169 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 9512,9523, 9527, 9630 true vertical 0 feet (true vertical) 6935,6942,6944, 7001 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 0 0 SURFACE 2750 9.625 2786 2386 0 0 PRODUCTION 10031 7 10065 7132 0 0 Perforation depth: Measured depth. Open hole 10065'-12921' True Vertical Depth. Open hole 7132'-7169' RECEIVED SCANNED .iii_ 2 )4 2jj1" JUL14 Z01� Tubing(size,grade,MD,and TVD) 4.5, L-80, 9717 MD, 7044 TVD Packers&SSSV(type,MD,and TVD) PACKER-3 74"UPPER WEATHERFORD ER PACKER @ 9512 MD and 6935 TVD AOG CC SPACER PIPE-4'SPACER PIPE-PATCH 0 9523 MD and 6942 TVD ,.JJ PACKER-3 74"LOWER WEATHERFORD ER PACKER 0 9527 MD and 6944 TVD PACKER-BAKER 5-3 PACKER 0 9630 MD and 7001 ND WRDP-SET CAMCO WRDP-2-BAL-SSA-S, (S#HSS-196)ON 4/9/2007 0 1836 MD and 1712 TVD 12.Stimulation or cement squeeze summary.N/A Intervals treated(measured) Treatment descriptions including volumes used and final pressure. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Daily Report of Well Operations r Copies of Logs and Surveys Run r Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25 070,25.071,825 283) 15.Well Class after work. Exploratory r Development 17 Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 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 Dusty Freeborn/Jan Byrne Email n1617@cop.com Printed Name Du r or Title Problem Wells Supervisor Signature Phone.659-7126 Date.12 July 15 VTI-- V—/ i/i5— Form 10-404 Revised 5/2015 RBD�Ol'I ►a� in1�15 Nov ConocoPhillips Alaska RECEDE® P.O. BOX 100360 JUL 14 2015 ANCHORAGE,ALASKA 99510-0360 AOGCC 12th day of July 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. CRU well CD 1-43 (PTD 200-106-0) and summary of work for a tubing patch to regain tubing by inner annulus integrity. Please call Jan Byrne or myself at 659-7126 if you have any questions. Sincerely, Dusty Freeborn Problem Wells Supervisor CD1-43 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/09/15 TIFL passed verifying integrity of the patch 06/28/15 Set upper Weatherford ER packer and spacer pipe with GL mandrel at 9512' 05/21/15 CMIT-TxIA passed proving integrity of lower Weatherford packer 04/27/15 Set lower Weatherford ER packer at 9532' 01/02/15 Attempted to set extended packing dummy in mandrel at 9520'. MITs failed 12/14/15 LDL identified a tubing leak at GLM#3 at 9520 11/14/15 Failed TIFL 10/30/15 Ops reported suspect TxIA communication during scale squeeze WNS PROD CD1-43 ConocoPhillips `" Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status rein MD(fIKB) Act Btm(ftKB) cr..,cornlliq 501032034400 ALPINE PROD 1 90.41 11,316.04 12,921.0 ... ...... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD1.43.7/720152'45'51 PM SSSV: Last WG'. 43.52 8/30/2000 • Vedcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 9.911.0 7/16/2008 Rev Reason:Pull WRDP,Set CSV,Set hipshkf 7/7/2015 Packer/Patch,GLV 0/0 1111 ' Casing Strings HANGER,326 • --11.-. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.697 36.4 2,786.1 2,385.9 36.00 J-55 BTC-MOD ■� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i s PRODUCTION 7 6.276 34.6 10,065.1 7,131.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 10,065.0 12,921.0 Tubing Strings pIIIrWp-91 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;41.a121.OJ TUBING 41/2 3.958 32.6 9,718.6 7,044.1 12.60 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;1636.e 32.6 32.6 0.00 HANGER FMC TUBING HANGER 4.500 • 1,836.8 1,712.5 41.16 NIPPLE CAMCO BAL-0 NIPPLE 3.812 • • 9,578.0 6,973.0 56.43 NIPPLE HES'X'NIPPLE 3.813 • • • 9,630.0 7,001.0 58.52 PACKER BAKER 5-3 PACKER 3.875 9,706.5 7,038.7 62.77 NIPPLE HES'XN'NIPPLE 3.725 9,717.4 7,043.6 63.43 WLEG WIRELINE ENTRY GUIDE 4.500 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl • Top(ftKB) (ftKB) (°) Des Goo, Run Date ID(in) SURFACE;36.42,786.1 9,511.9 6,935.4 54.42 PACKER 3.74"UPPER WEATHERFORD ER PACKER 6/28/2015 2.375 9,515.7 6,937.6 54.51 MANDREL 2-1/16"GLM w/1"OV,1/4"PORT 6/28/2015 1.900 9,522.6 6,941.6 54.67 SPACER 4'SPACER PIPE-PATCH 6/28/2015 2.441 PIPE GAS LIFT;4,216.2 Tr. 9,526.6 6,943.9 54.77 PACKER 3.74"LOWER WEATHERFORD ER PACKER 427/2015 2.375 9,706.5 7,038.7 62.77 VALVE 3.81"CAT SV(40"OAL) 3/3/2015 • • • • Stimulations&Treatments Min Top Mao Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (,KB) (ftKB) Type Date Co. 10,065.0 12,920.0 7,131.8 7,169.2 FRAC 4/6/2007 ALPINE SAND FRAC TREATMENT,PLACED GAS LP r,6 827.1 - 307,000#16/20 CARBITE INTO OPEN HOLE,IPPA ON FORMATION 111 10,065.0 12,920.0 7,131.8 7,169.2 REFRAC 4/23/2014 ALPINE SAND FRAC TREATMENT,PLACED 200,460#16/20 CARBITE INTO OPEN HOLE,8PPA ON FORMATION 111 Mandrel Inserts st - ati PACKER:9,511.87 on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD)In) Sery Type Type (in) (psi) Run Date Com { 4,216.2 3,401.6 CAMCO KBG-2 1'GAS LIFT 'GLV BK 0.188 2,066.0 6292015 6:00 MANDREL;8,515.7 2 6,827.1 5,201.8 CAMCO K8G-2 1 GAS LIFT GLV BK 0.188 1,901.0 6/29/2015 11:30 1 3 9,520.4 6,940.3 CAMCO KBG-2 1 GAS LIFT OPEN 4/2/2015 • GAS LIFT;9,520.4 iNotes:General&Safety SPACER PIPE;9,522.6 End Date Annotation 5/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER;8,526.6 1/11/2014 NOTE:Mandrel Orientation: 1)5:30 2)6:00 3)9:30 r ' 12/14/2014 NOTE:Unable to determine mandrel orientation at GLM 3 12/14/2014 NOTE:TUBING LEAK ID AT 9520"RKB'. NIPPLE;9,578.0 PACKER;9,6300 I NIPPLE;9,706.5 i VALVE:9,706.5 a A WLEG;9,717.4 PRODUCTREFRAC; EFRA34.;10,065.O ;C i RE FRAC;10,065.0 FRAC;10,0&5.0 Isla OPEN HOLE;10,065.012,921.0 PTD Zoo —/D( Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, July 02, 2015 9:36 AM To: 'NSK Problem Well Supv' Subject: RE:Alpine Producer CD1-43 (PTD #200-106) Request to bring online with no SSSV for patch diagnostics Dusty, Approval is granted to bring this well online without a SSSV for the purposes of diagnostic testing of the installed patch integrity. The period of time the well may be online without a SSSV is limited to one week to allow for this diagnostic testing. Thanx, Victoria Victoria Loepp SCANNED JUL 2 12015 Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loep00?alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: NSK Problem Well Supv [mailto:n16170conocophillips.com] Sent: Wednesday, July 01, 2015 9:18 PM To: Loepp, Victoria T(DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv; ALP Prod Engr; Adams, Mark V (SolstenXP) Subject: Alpine Producer CD1-43 (PTD #200-106) Request to bring online with no SSSV for patch diagnostics Victoria- Alpine Producer CD1-43 (PTD#200-106)was identified to have TxIA communication in Nov of 2014. Diagnostics proved that the gas lift mandrel at 9520'was leaking. The gas lift valve was pulled and reset in an attempt to repair the leak but the valve replacement did not fix the communication. A patch was recently set over the leaking gas lift mandrel and diagnostic testing is in process. Typically the lower packer is tested with a CMIT-TxIA. The upper packer of the patch is tested by setting a test tool in it and an MIT-T is performed. The well is then brought online and a TIFL is performed to verify patch integrity. The lower packer proved integrity with a passing CMIT-TxlAafter several attempts,the upper assembly passed an MIT-T after multiple attempts; however when the new gas lift design was set CPAI has been unable to achieve a passing MIT-T. Slickline has attempted to trouble shoot the failure source but cannot prove the source of failure. A failing MIT-T does not necessarily disprove integrity of the patch but is suspected to be due to the gas break out of the crude used for testing or the test tool set in the upper packer coming off seat. Because of the questionable results to the MIT-T CPAI is seeking permission to bring the well online without re-setting the sub surface safety 1 valve. The reasoning behind the request is to reduce the risk of un-necessary, repetitive work to the intervention crews. If the TIFL fails the SSSV, which would typically be re-set,will need to be once again removed for further diagnostics. If the TIFL passes the SSSV will be reset at the first available opportunity and proper paperwork for a successful patch set will be submitted in a timely manner. Please feel free to contact me with any questions regarding the request. Attached is a well bore schematic. Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 fl,WELLS TEAM ConocoPhillips 2 240- IOCo 2.5 1 c1 WELL LOG TRANSMITTAL DATA LOGGED 5 at/2015 M K.BENDER To: Alaska Oil and Gas Conservation Comm. April 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEWED MAY 0 6 2O1ib RE: Packer Setting Record: CD1-43 Run Date: 4/27/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-43 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20344-00 %CANWED JUN 1 5 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Ima~roject Well History File Coverage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RE~AN DIGITAL DATA Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERYL~A~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation + ~ = TOTALPAGES ~,.~ BY: BEVERLY ROBIN VINCENT SHERYL~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY: Stage 2 BY; IF NO IN STAGE 1, PAGE(S) DISCREPA/~~E BEVERLY ROBIN VINCENT SHERYL MARIA~ NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A~FENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASTS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) FOUND: YES NO RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • �('t�\��/%� HE STATE ' e_ci � L ` '` ;; -•'�-�i�•� ,', I 1 / �.77- ` 1-1,. .,,-- ---;"--77'. ..`7":-='-'--..7- l k s 1 ¢_ 333 Wag Seventh Avenue a <Y()V1.1��TC)IZ SEAN PARNI;I,I. Anchorage, Alaska 99501-3572 5 ,ys*'2: Main. 95i.279.1/133 €' ��A .L, Pex. 907.270.7`;42 Mike Hazen SCOAEll 1\II L;, ,/ Wells Engineer ConocoPhillips Alaska, Inc. a00,.-. 10 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD1-43 Sundry Number: 314-123 Dear Mr. Hazen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Y Cathy P Foerster Chair DATED this S day of March, 2014. Encl. • STATE OF ALASKA R E C t..; --' AL A OIL AND GAS CONSERVATION COMM, JN APPLICATION FOR SUNDRY APPROVALS MAR 0 3�S9 20 AAC 25.280q5 3 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Appk le Arcy Suspend r Rug Fbrforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate I—p , Alter casing r Other: r- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Development P., 200-106 ' 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20344-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P.• CD1-43 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25559- Colville River Field/Alpine Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12921 • 7169 • 12921' - 7169' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114' 114' SURFACE 2750 9.625 2786' 2386' PRODUCTION 10031 7 10065' 7131' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): open hole completion 10065-12921' , 7131-7169' 4.5 L-80 9719 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 5-3 PACKER • MD=9630 TVD=7001 NIPPLE-CAMCO BAL-O NIPPLE • MD=1837 TVD=1713 12.Attachments: Description Summary of Proposal P_ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development P• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2014 Oil r • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Hazen©265-1032 Email: Michael.C.Hazena,conocophillips.com Printed Name ike Hazen r Title: Wells Engineer Signature Phone:265-1032 Date 3M4-2:14 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 2,` ..t...`Z. Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMA.tilAY U 9 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /U -4 U[f APPROVED BY Approved by: ;i2-e4.-7(4,--- COMMISSIONER THE COMMISSION Date:3-5- / ApprovepRc tiost is valkp for J.2 months trom the date of approval. Form 10-403(Revised 10/2012) b ` 1\14 L_ .1)&1- 3/401 Submit Form and Attachments in Duplicate VLC3/c/1 g- 31',/1' CD1-43 Sundry Application Alpine well CD1-43 was drilled and completed in August 2000 as horizontal producer with 6/18" open hole completion from 10065' to 12921' MD. The well was previously fracture stimulated in April 2007 placing 307k#of 16/20 CarboLite proppant with 7-PPA on formation. The well has 4-1/2" 12.6# L-80 tubing from surface to 9718'MD. The well will be re-fracture- stimulated placing approximately 330k# 16/20 CarboLite in nine 0-8-PPA stages at 30-bpm. Proposed Procedure: Schlumberger Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 8 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 3195 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 172 bbl breakdown stage (linear gel) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Slowly increase annulus (IA) pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. -�- 11. Pump the Frac job by following schedule @ 30 bpm with a maximum expected treating pressure of 4000 psi. Stage 1 • 640 bbl Schlumberger fluid Pad • 180 bbl Schlumberger fluid w/ 1 PPA • 180 bbl Schlumberger fluid w/2 PPA • 210 bbl Schlumberger fluid w/3 PPA • 240 bbl Schlumberger fluid w/4 PPA • 270 bbl Schlumberger fluid w/5 PPA • 290 bbl Schlumberger fluid w/6 PPA • 290 bbl Schlumberger fluid w/7 PPA • 320 bbl Schlumberger fluid w/ 8 PPA • Flush with 155 bbl of linear fluid and freeze protect • Total Sand: Approx. 329,931-lb of 16/20 CarboLite Proppant 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). Cement Evaluation of CD1-43 and wells within 1/4 mile of CD1-43 CD1-43: 7" Casing two stage cement job was pumped on 8/23/2000. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plug was not bumped and float held. Full returns were observed during the job.' Casing was tested to 3500 psi for 30 min. CD1-40: 7" Casing cement job was pumped on 5/30/1999 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.2 ppg brine. The plug was bumped at 3500 psi and held for 5 minutes. The float held. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. • r . q 3 00 Boz • © � ¢ �3 »»> a x I E U• m • a% ` oc0(0o_ ZZZZZ � w ^^ s CL in a� m c c c c m .fa Y Z a 0. w 2 a2 p 2 Z o 0 0 0 > ; > ; > o y D U y •� e ix ce A O 3¢ o •a m m m 0 0 0 U U ya Z a 0 0 ¢ Q¢ •• a R • c p �Scna� 0_ 0 cccc¢ ¢ ¢ ¢ ¢ O � ¢U.. U_ \ S M zQ yea y c _ Q ,. U N o • /;' • ? 0. LL ••tCV :CO (n N •` O .Y'• N .Le••IP'•' Q 0 Z ,, cJ r` p • • t.• :..�� • _....• • o • rU• • U 4 Q • • M • •• U• M •t . . i r . ... \ o_•• :V Q 0.1 .• .. CV • :U•' : • v •• N • . Q CV Q / • U / • 'n • Q �. • d v N • U.• • "•• .l•• N •.•m• CV Q Q U CD C.), W .• Z U� Q• M • N . U o ..... ( • u :•• Z. N „ • . • • ay. i., J N `v^. ©• .. •• .lr (}�y. Stimulation Surface Rig-Up 0 Bleed f Tattle Tale Tank 1:1 at '" • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95%of max )8(10:01 0:1 Dal treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and mL' to:, set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. N N �\ r N � a ` 41 Q 4 L 4orui dwnd Pop Off Tank :11,3aci Pop-Off Tank D Pump Truck 0 rip N 14:11 dca.a C J V 4,2_ Frac Pump fJ 14.411 Frac Pump FraPump N .N Frac Pump Id-I- f )3. Proil ' Frac Pump Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) fl11:1:1ARAc,. l - ,i,,... A: ,..., . . . . _ Mt„.. : REMOTE OPERATED „TT„ . MASTER VALVE MOr MANUAL OPERATED rOr MASTER VALVE .egoal .r41'..r45:01 el . m_ Stinger I MANDREL t ..: 1. I I � 1 t /) VENT ti s.1®I f.—VALVE - - `‘ OPEN i' ISIS' %ttII IIII — ;111 e RJ . 10 r' FLOW TEE AND /(- VENT VALVE WELLHEAD IV—i�111 VALVES '7X41111111'///L OPEN L J- --t :i.-- .. IN WELLHEAD . ti..... CLOSES . D y ^r/ \ `\. i . . KL i J MI N OUAD PACKOFF ,n1 u\ ASSEMBLY IN � �` PLACE IN TUBING a TUBING 10 yrf • The universal tool is rated for 15,000 psi and has 84"of stroke. • Tool ID 2.25"down 4 '/2 tubing and 1.75"down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm TD -00 2 0 (Q 1L1 Cl) 1- 7--a 0 ac.iQ 0 0 0 0 0 0 0 0 0 0 o C a. 0 0 0 0 0 0 0 0 0 0 a 0 o cNi Co v ui cci 00 0 0 0 0 0 0 0 0 0 N N N N N N N (N y CD CO CO CD CO CO COO N 2 N O O O N N O O "O J J J J J J J J C 0 0 0 0 0 0 0 O C o Q 0 0 0 0 0 0 00 0 a` I. N 5 o 0 0 0 0 0 0 0 0 o a) (1) • o 10 LO L0 ori LOLI-51.0 «i 10U N N N N N N N N N N03 — T— a) o N M CD ' -0O7 a) `� CO N 0) Q (v Cl) 0'5 E o o 0 C 0 0 0 0 o cn U) CO f` N n Q y coSN N N N NCO ,- N C-- CO N-- O 0 - H 0 N CO o cf) U) LO LO LO LO LC) Ln LO N N N N N N N N N HSIIIM=1 co I LL TS _7 LL LL O (N CI U E o 0c)0 0 0 0 0 0 0 CO m a. -0 M co co co co co co Co M M N— a H < < < < < < < < u p J Q CL a. a_ Q a a. a - 1-0 N O a E � a a. a. a. a. a_ a_ a. ; N CD 0 0 0 0 0 0001 V' • w Z N Co V L c0 N- cci L LL > CO Oa1--+ 1--. cnowcz30 C coEc(ICIcii) oao M • OroMCOL() Oro CO O , - O > r r N. 1` 713 .r_- O 1` N. N. r O >' C •C gD) A-0 • O '5 •5 ci D E 5) °- -R. " (13 o (n t+- O TIO (1) = U O •a � QU CI: r;) ""1 O CO .t : Js C6 OUB C CI a) > E 4-,1 TD H o ca - a) •- o 1._ CO -0 o_ 4-, Io— CO i2 2 1-3 �.+ � . . � a O p L 0 2 . LI- = = L .5 O }+ O O C� v � = a 0a � a. L LL LL a) A L a) (i) -0ca f Q i Q) 0) L-- cnCO O = O > 0 c 'O a • = WQ N L } cNN•—e- _ n c cn -0 O = •- -0 -0 '— o (n (n O O O ()5 I— E N N E E 0 1 . a �_IJS PROD CD1-43 ConocoPhil lips �' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ConocoFhitlips 501032034400 ALPINE PROD 90.41 11,316.04 12,921.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) –Rig Release Date CD1-43,1/15/2014 1:38:08 PM SSSV: WRDP Last WO: 43.52 8/30/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 9,911.0 7/16/2008 Rev Reason:Mandrel Orientation,Pull/Reset hipshkf 1/15/2014 WRDP =T Casing Strings :m. HANGER;32.6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread II I SURFACE 95/8 8.697 36.4 2,786.1 2,385.9 36.00 J-55 BTC-MOD I 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 34.6 10,065.1 7,131.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 10,065.0 12,921.0 Tubing Strings I p,, , .,. . Tubing Description String Ma...ID(int Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 32.6 9,718.6 7,044.1 12.60 L-80 IBTM CONDUCTOR;41.0-121.0—a Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(5 Item Des Corn (in) 32.6 32.6 0.00 HANGER FMC TUBING HANGER 4.500 1,836.8 1,712.5 41.16 NIPPLE CAMCO BAL-O NIPPLE 3.812 WRDP;1,836.8 NIPPLE;1,836.81 ;iTX a 1 9,578.0 6,973.0 56.43 NIPPLE HES'X'NIPPLE 3.813 s c 9,630.0 7,001.0 58.52 PACKER BAKER 5-3 PACKER 3.875 9,706.5 7,038.7 62.77 NIPPLE HES'XN'NIPPLE 3.725 9,717.4 7,043.6 63.43 WLEG WIRELINE ENTRY GUIDE 4.500 Other In Hole(Wireline retrievable plugs,valves, pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 2.250 1,836.8 1,712.5 41.16 WRDP SET 3.812" DB LOCK ON WRDP(HPS-374)@ 1/14/2014 1837' Stimulations&Treatments SURFACE;36.4-2,786.1 Min Top Max Btm Depth Depth Top(TVD) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 10,065.0 12,920.0 7,131.8 7,169.2 FRAC 4/6/2007 ALPINE SAND FRAC TREATMENT,PLACED 307,000# 16/20 CARBITE INTO OPEN HOLE,IPPA ON FORMATION GAS LIFT;4216.2 - Mandrel Inserts St ati C on Top(ND) Valve Latch Port Size TRO Run o No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 4,216.2 3,401.6 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,677.0 4/9/2007 2 6,827.1 5,201.8 CAMCO KBG-2 1 GAS LIFT 'GLV BK 0.250 1,858.0 4/9/2007 3 9,520.4 6,940.3 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 4/8/2007 Notes:General&Safety GAS LIFT;6,827.1 C1 End Date Annotation 5/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1/11/2014 NOTE: Mandrel Orientation: 1)5:30 2)6:00 3)9:30 GAS LIFT;9,520.4 NIPPLE;9,578.0 or PACKER;9,630.0 NIPPLE;9,706.5 WLEG;9,717.4 PRODUCTION;34.6-10,065.1 1 I I I,- IIIIi FRAC;10,065.0 iirlt OPEN HOLE;10,065.0-12,921.0 STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS rm 1. Operations Performed: Abandon Repair well Pe r p r Plug P erforations r r Other iv.; Scale Inhibition Treatment Alter Casing r Pull Tubing r Stimulate - Frac `° Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r - 200 - 106 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 - 103 - 20344 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559 •• CD1 -43 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,, none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12921 feet Plugs (measured) none true vertical 7169 feet Junk (measured) none Effective Depth measured 12921 feet Packer (measured) 9630 true vertical 7619 feet (true vertucal) 7001 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114 114 SURFACE 2750 9.625 2786 2386 PRODUCTION 10031 7 10065 7131 - , ;y.,ifl-... ,,riR`- RECEIVED Perforation depth: Measured depth: open hole completion 10065'- 12921' True Vertical Depth: 7131' -7169' AUG 1 5 2012 AOGCC Tubing (size, grade, MD, and TVD) 4.5, L -80, 9719 MD, 7044 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 5 -3 PACKER @ 9630 MD and 7001 TVD SSSV - CAMCO BAL -0 SSSV @ 1837 MD and 1712 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10065' - 12921' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 377 1688 227 -- 172 Subsequent to operation shut - in for plant turn around 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development F7 c Service r Stratigraphic r 16. Well Status after work: 4. Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ E SUSP r SPLUG r 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: none Contact Michael Dammeyer nu. 265 -6548 Printed Name Michael Dammeyer Title Senior Production Engineer Signature Phone: 265 -6548 Date 0/......x. q' t 3 /1 *-Mr\ Form 10 -404 Revised 11/2011 REIDMS AUG 15 2012 AA/kV Submit Original Only WNS • CD1 -43 Cand P hillips ) Well Attributes Max Angle & MD TD Alaska 11 J Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 501032034400 ALPINE PROD 90.41 11,316.04 12,921.0 Comment H2S (ppm) Date Annotation End Date KB.Grd (ft) Rig Release Date — SSSV: WRDP Last WO: 43.52 8/30/2000 Well Conk! - CD7-43, 3/19/2011 10'.17.54 AM Schema[ is -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 9,911.0 7/16/2008 Rev Reason: SET WRDP; PULL ISO SLEEVE Imosbor 3/19/2011 ________________________ Casing Strings Casing Description String O String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1' g!: , CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H WELDED HANGER, 33 " Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.697 36.4 2,786.1 2,386.0 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 111 — 1 P PRODUCTION 7 6.151 34.6 10,065.1 7,131.0 26.00 L -80 BTCM Casing Description String O . String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd OPEN HOLE 6 1/8 6.125 10,065.0 12,921.0 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd ? TUBING 41/2 3.958 32.6 9,718.6 7,044.1 12.60 L -80 IBTM ( Completion Details CONDUCTOR, , Top Depth 41 -121 [_ (TVD) Top Intl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 326 32.6 -0.69 HANGER FMC TUBING HANGER 4.500 1,836.8 1,712.3 41.16 SAFETY VLV CAMCO BAL-0 SSSV 3.812 WRDP, 1,837 - -- -- 9,578.0 6,972.9 56.43 NIPPLE HES'X' NIPPLE 3.813 SAFETY 1,8 i O 9,630.0 7,001.0 58.52 PACKER BAKER 5-3 PACKER 3.875 9,706.5 7,038.6 62.77 NIPPLE HES 'XN' NIPPLE 3.725 9,717.4 7,043.5 63.43 WLEG WIRELINE ENTRY GUIDE 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (kKB) (ftKB) ( °) Description Comment Run Date ID (in250 ) 1,836.8 1,712 41.16 WRDP SET 3.812" WRDP (HSS- 125) 3/18/2011 2 . Stimulations & Treatments Bottom SURFACE, Min Top Max Btm Top Depth Depth 36 -2.788 Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) ( ftKB ) Type Date Comment 10,065.0 12,920.0 7,131.0 7,169.2 FRAC 4/6/2007 ALPINE SAND FRAC TREATMENT, PLACED 307,000# 16/20 CARBITE INTO OPEN HOLE, 7PPA ON FORMATION 045 LIFT. Notes: General & Safety 4 216 ......„, ., End Date Annotation 5/17/2009 NOTE: VIEW SCHEMATIC w /Kaska Schematic9.0 GAS LIFT, 6 al 627 GAS LIFT. 4 C.,.. 9,520 NIPPLE, 9,578 PACKER. 9,630 V°,% y NIPPLE. 9,707 WLEG, 9,717 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run I Stn Top (ftKB) (MKS) 6) Make Model (in) Sery Type Type ON (psi) Run Date Corn... 1 4,216.2 3,403.5 45.74 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,677.0 4/9/2007 2 6,827.1 5,201.9 51.04 CAMCO KBG-2 1 GAS LIFT GLV BK 0.250 1,858.0 4/9/2007 - 3 9,520.4 6,940.3 54.62 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 4/8/2007 PRODUCTION, '.o 11 35-10,065 I • 0 FRAC, 10,085 • • OPEN HOLE, 0 10,065- 12,921 " • ID, 12.921 • S Scale Inhibition Treatment: CD1 -43 8/4/2012: Initial pressure TBG/IA/OA — 400/900/730; Facility pumped 50 bbls SW preflush; LRS pumped 1.6 bbls WAW5206 (67 gal) at 0.35 bpm and facility pumped 15 bbls SW at 3.7 bpm, 400/900/740; LRS pumped 15.7 bbls SCW3001WC (660 gals) at 0.6 bpm and facility pumped 89 bbls of SW at 4 bpm, 550/910/740; LRS pumped 1.6 bbls WAW5206 (67 gal) at 0.35 bpm and facility pumped 15 bbls SW at 3.7 bpm, 450/910/740; facility pumped 862 bbls of SW over - displacement at 4.3 bpm. ALASK~L AND G STCONSERVAT ON COMMIS~J RECEIVED REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon "' Repair w ell ~ Plug Perforations ~ Stimulate r Ot er Alter Casing ~` Pull Tubing ~'"` Perforate New Pool '°" Waiver BSk~~rC, COtI'S111SS{0t1 Change Approved Program ~ Operat. Shutdown " Perforate r Re-enter Suspended, ~~~ 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 200-106 3. Address: ~6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 Stratigraphic ~""' Service 50-103-20344-00 7. Property Designa~on: 8. Well Name and Number: ~ CD1 43 ADL 25559 - 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 12921 feet Plugs (measured) None true vertical 7169 feet Junk (measured) None Effective Depth measured 12921 feet Packer (measured) 9630 true vertical 7619 feet (true vertucal) 7001 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114' 114' SURFACE 2750 9-5/8" 2786 2386 PRODUCTION 10031 7 10065 7131 Perforation depth: Measured depth: open hole completion 10065'-12921' , True Vertical Depth: 7131'-7169' ~`« '' ~' `_ '°Y~' `f ~` ` ! ~ s%,i Tubing (size, grade, MD, and TVD) 4.5, L-80, 9717 MD, 7044 TVD Packers &SSSV (type, MD, and TVD) PACKER -BAKER 5-3 PACKER @ 9630 MD and 7001 TVD SAFETY VLV - CAMCO BAL-O SSSV @ 1837 MD and 1713 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 10065'-12921' Treatment descriptions including volumes used and final pressure: 99 gal WAW 5206 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 226 1262 384 -- 181 Subsequent to operation 430 2341 325 -- 185 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service ~ . Well Status after work: Oil ~`' Gas WDSPL ]'~`; Daily Report of Well Operations XXX GSTOR ~" WAG '"' GASINJ ~ WINJ `"`' SPLUG `";, 16. 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: none Contact Tim Schneider Cad 265-6859 Printed Name Tim Sc Heider Title Alpine Staff Engineer Signature Phone: 265-6859 Date ~ ~ /~,. /d ,. / RBDMS JUN 0°210 ~" Z -~a Form 10-404 Revised 7/2009 ~ '' Submit Original Only ~~ G CD1-43 Well Events Summary DATE SUMMARY 5/8/10 Aqueous Scale Inhibition treatment mped 9:00 to 10:41. Initial tubing pressur~0 psi. Pumped 24 bbls SW /WAW 5206 (99 gal WAW 5206), 158 bbls SW /SCW 3001 (990 gal SCW 3001), 24 bbls SW /WAW 5206 (99 gal WAW 5206), at a pump rate of 6 bpm. Displaced with 1153 bbls SW. Final tubing pressure 300 psi. Cc~rtc~ciPhiitips lI •>nkA, V~1. lid CON wF SAI NIP PACT NIP WI PRO FR Of '.O.i WNS ~ CD1-43 Well Attribut __ ~~ es Max A ngle & MD TD Wellbore API/UWI Fieltl Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 501032034400 ALPINE ,PROD 90.41 11,316.04 129210 jComment IH2S (ppm) Date Annotation End Date ~'~iKB-Grd (ft) Rig Release Date '~.SSSV: WRDP ( ( ( Last WO: 8!30/2000 _ Annotation Depth (ftKB) ~.iEnd Date Annotation Last Mod... End Date !Last Tag' I 9,911.0 ~ 7/16/2008 (Rev Reason: OC (ALLIES Imosbor 5/23/2010 ~Casing_Strin --- ~s - - -- - Casing Description CONDUCTOR String 0... 16 String ID ... 15.062 Top (ftKB) 410 epth ( ... Set 121.0 et ept ( ) ... 1210 ng ... 62.58 ng ... H-00 g r op WELDED _ Casing Description String 0... String ID ... Top (ftKB) Set Depih (t... Set Dap[h (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.697 36.4 2,786.1 2,386.0 36.00 J-55 BTC-MOD Casing Description String 0 ... String ID ... Top (ftKB) Set Depth (t... Set Depth (ND) _. String WI... String ... String Top Thrd PRODUCTION 7 6.151 346 10,065.1 7,131.0 26.00 L-80 BT~CM Casing Description String O ._ String ID ... Top (ftKB) Sat Depth (i... Set Depth (ND) ... String Wt... String ._ String Top Thrd OPEN HOLE 6 1/8 6.125 10,065.0 12,921.0 Tubin Strin s Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wi... String ._ String Top Thrd I TUBING 41/2 3.958 326 9,718.6 7,044.1 12.6.0 L-80 IBTM I ,Completion Det Top Depth I ails (ND) Top Inc! N mi... p ( (kKB) To (°) Item D scription Comment ID (in) 32 6 32.6 -0.69 HANGER FMC TUBING HANGER in T Thrd Stri Wt Stri St D f S D h ND 4 500 Run Date ~.~ Min TOp Max B[m Depih Depth (ftK8) (ftKB) Depth (TVD) ~ (ftKB) 7.169.21 F RAC ALPINE SAND FRAC TREATMENT. PLACED 307,000# 16/20 CARBITE INTO OPEN HOLE, 7PPA ON FORMATION Port OD Valve Latch Size TRO Run Model (in) Serv Type Type (in) (psi) Run Date Com... KBG-2 1 GAS LIFT GLV BK 0.188 1,677.0 4/9!2007 KBG-2 1 GAS LIFT GLV BK 0.250 1,858.0 4/9/2007 .KBG-2 1 GAS LIFT OV BK 0.250 0.0 4/8!2007 i~EC~~~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ,Jl'~ ire tti {' _''~j REPORT OF SUNDRY WELL OPERATIQNS~.. ~ ~, _ __..__._._ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Oth r ~ scale squeeze . c' ~l"tGi f> Alter Casing ^ .Pull Tubing ^ Perforate New Pool ^ ~ Waiver ^ Time Extension ~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^~ Exploratory ^ 200-106 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20344-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD1-43 8. Property Designation: 10. Field/Pool(s): ADL 25559 • Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12921' feet true vertical 7169' feet Plugs (measured) Effective Depth measured 12921' feet Junk (measured) true vertical 7169' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 2750' 9-5/8" 2786' 2386' PRODUCTION 10029' 7" 10065' 7131' __ ~. Perforation depth: Measured depth: open hole completion fro m 10065'-12921' true vertical depth: 7131'-7169' „ ~., dw+ti~~1 tit;~ ^•~ y 1 ~~+~ ~ ~(~~~ d~ '° Tubing (size, grade, and measured depth) 4.5", L-80, 9719' MD. Packers &SSSV (type & measured depth) Baker S-3 pkr @ ss3o' Camco BAL-O SSSV ~ 18 37' 12. Stimulation or cement squeeze summary: Intervals treated (measured) see attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 440 1714 241 -- 180 Subsequent to operation 565. 1391 282 -- 182 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Ti chneider Title Alpine Staff Engineer `/ Signature Phone: 265-6859 __ Date f~'-s '~7 Pre are b Sharon Al/s -Drake 263-4612 " - _ . ~ mil! ~~~~ ~ ~ 2D~9 ~ ~6~~ ~ ~-~ ~~ Form 10-404 Revised 04/2006 r ~ ~ 3 Submit Ori final Onl ~~~ WSR -Well Service Report Well Service Report C~ Page 1 of 1 Well .Tob Scope CPAI Rep CD 1-43 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 5/16/2009 32 n~ is T/I/A Initial - 550/850/800 Final Field; ALPINE Final - 1050/725/800 Pressures: Pump an Aqueous Scale Inhibition treatment into well. Pumped 12.2bbls 2~ hr, SW+5206, 90.8 bbls SW+3001, 12.2 bbls SW+5206. Tried to displace with SW Summary but only pumped 46.6 bbls due to pressure restriction. Pumped 34 bbls diesel freeze protect in SOmins. STtiRTTIM:E OPERATLON 07:00 PM Rig in and pressure test lines to 2000psi. Pump 12.2 bbls SW+5206 followed by 90.8bbls SW+3001 chemical. Pumped flush 08:00 PM 12.2bbls SW+5206 and followed with 46.6 bbls SW before pressuring up well. Pressure climbed from 425 psi - 1300psi. Initial volumes pumped at 4.Obpm, down t 0.9bpm at 1300psi. 09:00 PM Pumped freeze protect 34 bbls, at 500-1300psi and 0 - 1 bpm. 10:00 PM Shut down, rig out equipment and return to base. Fluid Type To Well From Well Non- recoverable Note DIESEL 34 SEAWATER 47 SEAWATER, SCW- 91 3001 WC SEAWATER, WAW- 24 5206 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=2770CEA8... 6/5/2009 ~, CD1-43 _`~ a -- WNS V . _ _ ~ ( ( ) CQ111CKOP~'11~~Ip5 i ~! Well Attnbutes Max Angle 8 MD I~TD AI .,_µ ,I W Ilbo APUUWI F Id Name Well Status Inc! °I MD HKB !Ad Bfm (HKB) ~ 501032034400 (ALPINE _ PROD 90 41 11,316.04 12,921.0 Dace HANGER. 33 CONDUCTOR. 0-121 SSSV. 1.e3] WRDP, 1,83] SURFACE. 36-2.]86 GAS LIFT. 6.218 GAS LIFT, 6.82] GAS LIFT, 9,520 NIPPLE, 9.5]8 9.630 NIPPLE, 9.]0] WLEG. 9.]t] PROOUCnoN, 3s-16,6ss FRAC, 10.065 OPEN HOLE. 10,065-12.921 TD, 12,921 Last Tag' ~ 9,911.0 7/16/2008 (Rev Reason SET WRDP ~ Imosbor 5!17/2009 __.._ ca~ln„ ctr;n„~ _ -- Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 0.0 121.0 121.0 ' WELDED 62.58 H~0 Casing Description String 0... String ID ... Top (HKB) Se[ Depth (f... Set Depih (ND) ... _ String Wt... String ...String Top Thrd SURFACE 95/8 8.697 364 2,786.1 2,386.0 36,00 J-55 BTC-MOD Casin Descri tion 9 P Strin 0...Strin ID ... 9 9 To (HKB) P Set Do th f... P( Set De ih ND)... P( Strin Wt... Strin String TOp Thrd 9 9~~~ PRODUCTION 7 6.151 34.6 10,065.1 ( 7,131.0 2600 L-80 ~' BTCM ___ Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... : String Wt... String ... ~. String Top Thrd OPEN HOLE ~ 61/8 6.125 10,065.0 12,921.0 Tubin Strin s Tubing Description String 0... String ID ... Top (HKB) Set Depth (f... Sel Depth (ND) ... String WI... String ... String Top Thrd TUBING 41/2 3.958 32.6 9,718.6 7,044.1 12.60 L-80 IBTM _ ____ _ Completion De Top Depth i tails - - (ND) ', Top Intl Top (HKB) (kK6) '~ (°) Item Description Comment ID (in) 3261 32.6 -0.69 HANGER FMC TUBING HANGER 4.500 1,836.8 1,712.3 41.16 SSSV CAMCO BAL-O SSSV 3.812 9,578.0 6,972.9 56.43 NIPPLE HES'X' NIPPLE 3.813 9,630.0 7,001.0 58.52 PACKER BAKER 5-3 PACKER 3.875 9,706.5., 7,0386, 62.77, NIPPLE HES'XN'NIPPLE 3.725 2717.4 l.0435~ 5343 WLEG WIRELINE ENTRY GUIDE 4.500 Other_In Hole ( -. __ Wireline retrievable plugs, valves, pumps, fish, etc.) __ ___ __ Top Depth (TVD) Top Intl Top (HKB) (HKB) (°) Dasc iption Comment Run Date ID (in) -~--_-_--- 1,837 1.712.3 lations 8 Sti 41.16~WRL7P ~3.812"WRDP (SS-125) 5/8/2009 2.250 Treatment mu s Bottom Min Top Maz Btm Top Depth Depth ' Depth Depth (HKB) (HKB) (ND) (TVD) (HKB) (HK6) Type Date ~ Comment _ _ 10,065.0 12,921.0 7,131.0 FRAC 4/6/2007 ALPINE SAND FRAC TREATMENT, PLACED ( ~I 307,000# 16/20 CARBITE INTO OPEN HOLE, 7PPA ION FORMATION Notes: Ge_n_er al & Safety _ Entl Date Annotation _ _ 5/172009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Top Depth Top ~ 'i PoA (TVD) Intl OD Valve Lalch Size TRO Run S_tn To (HKB! (HKB) (°) Make Model _ _ (in) Serv Type Type (in) (psi) Run_Date Cam... 1 4216.2. 's,403.545.741CAMCO KBG-2 1GAS LIFT GLV BK X0.188,, 1,677.04/9/2007 2 6.827.1 5,201.9 51.04CAMCO KBG-2 1 GAS LIFT GLV BK 0.250 1,8580 4/9/2007 3 9,520.4 6,940.3 54.62ICAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 4!8/2007 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS - u,..~ 3 / s , ~) 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^Q - Other ~itit,(iiiE' Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 200-106 / 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchora e, Alaska 99510 50-103-20344-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' ~ CD1-43' 8. Property Designation: 10. Field/Pool(s): ADL 25559 .Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12921' ~ feet true vertical 7169' feet Plugs (measured) Effective Depth measured 12921' feet Junk (measured) true vertical 7169' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 2750' 9-5/8" 2786' 2386' PRODUCTION 10029' 7" 10065' 7131' Perforation depth: Measured depth: open hole completion 10065'-12921' true vertical depth: 7131'-7169' = ~° ~+~? ~s ~ ~~~?~? Tubing (size, grade, and measured depth) 4.5", L-80, 9719' MD. Packers &SSSV (type & measured depth) Baker'S-3' pkr @ ss3o' SSSV= 1836' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 104 bbls SW+WAW5206, refer to attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 595 1962 270 -- 181 Subsequent to operation 596 2041 219 -- 182 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Ti S~ eider ~ Title Ph 265 6859 Alpine Staff Engineer ~`Z ~" _O D t Signature one: - a e Pre ared b Sharon All u Drake 263-4612 Form 10-404 Revised 04/2006 Submit/Origin I Only WSR -Well Service Report • Well Service Report Page 1 of 1 Well aob Scope CPAL Rep CD 1-43 Scale Inhibition Barreda, Brian Date Daily Work Unit Number 4/10/2009 Scale Squeeze 32 Initial & T/I/A Start 400/800/825 Final Pressures: T/I/A End 1550/700/850 Field: ALPINE Pum A ueous Scale Treatment. Pum ed 104 bbls SW+WAW5206 at 2-4 bpm 24 hr. followed by 12bbls SW+WAW5206 pre flush and 79 bbls SW+SCW3001 WC. summary Ran into high pressure during displacement 1600 psi and had to shut job down. ~ well and freeze protect well with 47 bbls utilizing plant AHF pump. STriRTTIME OPERAT.IO'_Y 06:25 PM Stage 1 -pump 104 bbls SW+WAW5206 at 6.5 bpm, pressure from 400 psi down tc vac 07:22 PM Stage 2 -pump 12 bbls SW+WAW5206 4bpm, pressure from 700 psi -vac. 07:31 PM Stage 3 - 79bbls SW+SCW3001 WC start pumping well on vac and increasing to 801 Stage 4. WHP increased 1500 ps while pumping 0.5 - 1 bpmi during over- 08:04 PM displacement. Contact PE. PE recommends shutting down the job and freeze protecting 08:34 PM Freeze protect well with 47 diesel through use of plants AHF pump. Fhiid Type To Welfi .From Well .lion- recoverable Note DIESEL 47 Freeze Protect SEAWATER 37 SEAWATER, SCW- 79 3001 WC SEAWATER, WAW- 1040 5206 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=7B3C 172... 4/22/2009 ~(~Y~~~~'ll~~l~S ... +~ tsk4 f/x:_ col Wi r WNS ~ CD1-43 ,Well Attributes Wellbore APl/UWI _ Fieltl Nama Wall StaWS Maximu I clination (°) Total Depth (HKB) 501032034400 (ALPINE PROD I, 90.41 I 12,921.0 Annotation End Date KBG d(H) Comment H2S (ppm) ' Data Rig Release Date WRDP ( ( ( ( Last WO: i 8/30/2000 ,^ -' Annotation 'Depth (HKB) End Data Annotation ', End Date Last Tag: 9,911.0 7/16/2008 Rev Reason: POST FCO TAG, SET WRDP 8/7/2008 - Casin Strin s Set Depth Set Depth (TVD) WI Casing Description OD (in) ID (in) Top (HKB) (ttK6) (ftK8) (Ibs/H) Gratle Top Thread - CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-00 WELDED SURFACE 9 6/8 8.697 0.0 2,786.0 2,385.9 36.00 J-55 BTC-MOD PRODUCTION 7 6.151 0.0 10,065.0 7,131.0 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.125 10,065.0 12,921.0 Tubing Strings . Set Depth __ __- Tubing Description OD(in) ID (in) Top (HKB) !ftK8) Set Depth (TVD)(HKB) Wt(IbsXt) Grade Top Thread TUBING 41/2 3955 00 9,719.0 1.044.3 12.60 L-80 IBl"M Other In H ole Al Run & Retrievable, Ftshz etc.1 l Jewel : Tubing Top (ftK8) _ Descripti on . _ _ _ Comment Run Date ID (in) 1,836.0 SSSV WRDP CAMCO BAL-O NIPPLE 8/26/2000 3.812 1,836.0 WRDP 3.812" WRDP-2 (HVS-266) 7/28!2008 2.250 4,216.0 GAS LIFT CAMCO/KBG-2/1/GLV/BK1.188/1677/Comment ST AI 419/2007 3.938 6,827.0 GAS LIFT CAMCO/KBG-2/1IGLV/BK/ 25/1858/Comment: STA 2 4/9/2007 -3.938 9,520.0 GAS LIFT CAMCO/KBG-2/1/OV/BK/.25// Comment: STA 3 !4/8!2007 3.938 NIPPLE Depth (HKB) 7PPA ON FORMATION NIP SAC NIF W PRC FR OI ~ , STATE OF ALASKA ~~)~~ ALASKA OIL AND GAS CONSERVATION CC~I~IS{~I REPORT OF SUNDRY W~~~~' ~Q~issi~t~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stirr?iq ~~$ • Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^~ ' Exploratory ^ 200-106 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20344-00• 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD1-43 8. Property Designation: 10. Field/Pool(s): ADL 25559 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12921' feet true vertical 7169' • feet Plugs (measured) Effective Depth measured 12921' feet Junk (measured) true vertical 7169' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 2750' 9-5/8" 2786' 2386' PRODUCTION 10029' 7" 10065' 7131' Perforation depth: Measured depth: open hole completion 10065'-12921' true vertical depth: 7131'-7169' r Tubing (size, grade, and measured depth) 4.5", L-80, 9719' MD. Packers &SSSV (type & measured depth) Baker'S-3' pkr ~ ss3o' SSSV= 1836' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 104 bbls SW+WAW5206, refer to attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 697 1637 195 -- 180 Subsequent to operation 570 1932' 213 -- 181 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^' Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Tim Schneider Title Alpine Staff Engineer Signature •,.._---- Phone: 265-6859 ~/ o Date /"fa "~ Pr ared b Sharon All u Drake 263-4612 ., r~ I ~ ~ ~~ /~ ~ ti ~ MAY ~ ~ ~DO~ ~ ~/i~ ./~ y r~~ `~ Form 10-404 Revised 04/2006 ~'°t Submit Original Only ^ ,r. ~C)I'15~0~1i~~1p5 A`a~s~+.;t. Inr, '• WNS ~ ~ ~ Well Att Wellbore AF ! 50103" com eat 9. Depih ', Depth (HKB) '~ (fiKB) Nama • Comment: STA2 lent STA 3 SAND FRAC TREATMENT, F HOLE, 7PPA ON FORMATION CD1-43 12,921.0 elease Date 8/30/2000 CD1-43 Well Work Summary DATE SUMMARY 3/20/09 Pump Aqueous Scale Treatmen~umped 104 bbls SW+WAW5206 at 6.5t~min followed by 12bbls SW+WAW5206 pre flush and 60 bbls SW+SCW3001WC. Ran into pressure and had to shut job down. Flow back ~67 bbls fluid and freeze protect well with 47 bbls utilizing plant AHF pump. L 11~/111V VViA1V Al ~I MVV/~VJ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Monday, September 15, 2008 10:26 AM To: 'Schneider, Tim S.' Cc: Haas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes Tim, et al, It is acceptable to perform these operations without submitting a sundry. Be sure that the work is documented by submitting a 404 with appropriate attachments. Call or message with any questions. Tom Maunder, PE AOGCC 1 ~5., 1 ~l From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophiltips.com] Sent: Monday, September 15, 2008 9:54 AM To: Maunder, Thomas E (DOA) Cc: Naas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes Tom, Per our conversation, here is our preliminary list of wells we'd {ike to perform scale squeezes on. CD2-34 (201-191) CD1-27 (200-006) GD1-35 (199-038) CD1-43 (200-106) -~r- CD2-50 (202-049} ~~N~~ ~i_t~ ~ b ~~~~ We'll incorporate in our plans to submit 10-404's to provide AOGCC with a summary of the treatments: Thanks Ti m From: Schneider, Tim S. Sent: Monday, September 15, 2008 9:26 AM To: 'Maunder, Thomas E (DOA)' Subject: RE: Alpine Scale Squeezes Tom, We will be treating the producers: Rough volumes: Producers with watercut < 25% 60 bbl inhibitor pill (85% MEG, 15% scale inhibitor) Flush wRl be with dead Alpine crude (350-450 bbls} • Will attempt to stay below frac gradient (varies from 0.5-0.6) We need to treat as much of the ON as is possible due some GR logs run in August that indicate the presence of Barium scale within the reservoir. This will require that we stay below the frac gradient. Even distribution is the 9/15/200% AltJLIlV I.JV41V V1164V\+LVJ s .,., ~ ~ '~ ~, t~. ^a°! `,~ .,,;,' oe did`?cia,? • for ~_~od~;certi +.;vith ~,,,°atvrcu > 2~°f~ wa'1'=. rQpiaoe the ~i1~G ~,aith saavvat?r as waif as the flush. iu~v~.viv ;,~1e plan to perform a~ +tileiis prior to the ice road season to e~,raluate results and impro~>e upon our procedures for up to 2g treai!~e~ is during ice road (dependent on ~U time-simops, etc.) The scale inhibitor designs are based on core work done in 20G2-2©04 to determine a scale inhibitor that would not damage the Alpine reservoir and we were able to identify a product (acrolyte vs. a phosphonate (used at GKA}) that doesn't damage the reservoir. Afield test has not been performed, but the scale inhibitor product is currently being used for surface scale management. Hope this helps explain our plans. Let me know if further information is needed. Thanks, Tim From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 15, 2008 9:13 AM To: Schneider, Tim S. Subject: RE: Alpine Scale Squeezes Tim, Can you give me an idea of the number of wells, injectors or producers and general procedure? Thanks, Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Monday, September i5, 2008 9:12 AM To: Maunder, Thomas E (DOA) Subject: Alpine Scale Squeezes Tom, We are planning to perform scale squeezes at Alpine to control barium sulfate scale deposition. Our goal will be to inject below parting pressure. Is a 10-403 required to perform these? Thanks, Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine 'J? Phone: 907-265-6859 S' Fax: 907-2656472 <s+ Mobile: 907-632-8136 Email: film_s.schneider@conocophillips.com 9/15/2008 ~/ ~,:lP,(),1 RECEIVED .~ STATE OF ALASKA ~/~ù APR ALASKA OIL AND GAS CONSERVATION COMMISSION 1 9 7007 REPORT OF SUNDRY WELL OPERATIONSlaska Oil & Gas Cons. Commission 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate [2] Other An@Þrage Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [2] Exploratory D 200-106 (' 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20344-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' < CD 1-43 <' 8. Property Designation: ADL 25559 I 11. Present Well Condition Summary: 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool Total Depth measured 12921" feet true vertical 7169' , feet Plugs (measured) Junk (measured) Effective Depth measured feet true vertical feet Casing Structural CONDUCTOR SURF CASING PROD CASING OPEN HOLE Length Size MD TVD Burst Collapse 121' 2786' 10065' 2856' 16" 9-5/8" 7" 121' 2786' 10065' 12921' 6-1/8" SCANNED APR 2 5 2007 Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9719' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'S-3' PACKER pkr= 9630' SSSV= NIP; SSSV SSSV= 1836'; 1836' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: S BFl APR 2 4: 2007 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 1561 1872 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 4055 24 3599 172 15. Well Class after work: Exploratory D Casing Pressure 604 780 Tubing Pressure 213 210 13. Development [2] Service D 16. Well Status after proposed work: Oil [2] GasD WAGD GINJD WINJ D 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: 307 -123 Daily Report of Well Operations _X WDSPLD Contact Printed Name Signature Maria Kemner ~~. ria Kemner '-'r11\~ ~~ ORIGINAL Title Phone Production Engineer 265-6945 Date oY ltq { 1/1- Form 10-404 Revised 04/2006 Prepared by Jeanne Haas 263-4470 ~# Submit Originai Only ~ "-" CD1-43 Stimulation results: Summary of stimulation job: 4-06-07: Pump frac stages in stair steps; 2, 4, & 7 PPA, 3061 bbls total slurry, 165 bbls diesel for freeze protect. AIR-40 BPM, AIP-400 psi, ISIP-48 psi. 312,000 Ibs. 16/20 Carbolite in perfs. Well test: 4/13/07: 1872 bopd, 172 bwpd, 3.6 mmcfpd, 210 WHP . ~1T&\1TŒ ffi)~ ~~&\~æ&\ . AI~~1iA. OIL AlQ) GAS CONSERVATION COMMISSION / SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Maria Kemner Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 t00 ;;00; Re: Colville River Field, Alpine Oil Pool, CD 1-43 Sundry Number: 307-123 SCANNED APR 1 1 2007 Dear Ms. Kemner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this If) day of April, 2007 Enc!. . . D7S <CfjC¡/; ~t:\ RECEIVED .~ APR 0 9 2UUl ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRovA{aska Oil.& Gas Cons. Commission 20 MC 25.280 Anchorage STATE OF ALASKA 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 , Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-1 06 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20344-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0' CD1-43 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25559 ' RKB 36' Colville River Field 1 Alpine Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12921', 7169' . Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' SURF CASING 2786' 9-5/8" 2786' PROD CASING 10065' 7" 10065' OPEN HOLE 2856' 6-1/8" 12921' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 9719' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'S-3' PACKER pkr= 9630' SSSV= NIP; SSSV SSSV= 1836'; 1836' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 0 - Service 0 Development 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 13, 2007 Oil 0 - Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify tha;~lf~regOing is true and correct to the best of my knowledge. Contact: Maria Kemner Printed Name ~;J1: ria Kemne Title: Production Engineer ¡b~ Signature \... i I: / ! (1 JIM '--' 0 ßV\ ./\I1a.A Phone 265-6945 Date D 4 ¡ 0 ~ \.,. ¡ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry N(~r:'7 -* / a. .9 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent Form Required: \..\() ~ ----< RBDMS BFL APR 1 1 2007 APPROVED BY Date: L/R,. Approved by: THE COMMISSION Form 10-403 Revised 06/2006 U ~ ~L'-- /q;~/ bmitin ~ t.(. '.t> ~~ 7 . . . Overview: ( CD1-43: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. 1"his will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 30 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. ~~\~~~~~\",~'c~~ ~~~O ?<;.. \ ~ '-ll""" -C~. · 300 bbls YF125ST Pad 240 bbls YF125ST wI 2 ppa 16/20 Carbolite 480 bbls YF125ST wI 4 ppa 16/20 Carbolite 1000 bbls YF 125ST w/ 7 ppa 16/20 Carbol ite Flush with linear YF125ST and freeze protect · · · · Total Sand: -310,000Ibs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 scAN~IE.D A PR 1 () 2007 , ;lOO-1 Dip Dear Mr. Maunder: -, -,"" '~~. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 Alpine Field March 31,2007 F:\LaserFiche\CvrPgs_lnserts\M icrofilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ..;'Ú" ') ) APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 36 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 servia__ Colville River Unit 4. Location of well at surface 8. Well number 523' FNL, 3000' FEL, Sec. 5, T11 N, R5E, UM (asp's 385703, 5975608) CD1-43 At top of productive interval 9. Permit number / approval number 1343' FSL, 1894' FWL, SEC. 6, T11 N, RSE, UM (asp's 380378, 5972281) 200-106 At effective depth 10. APl number 50-103-20344 At total depth 11. Field / Pool 1316' FNL, 1527' FEL, Sec. 7, T11 N, R5E, UM (asp's 381823, 5969594) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 12921 feet Plugs (measured) true vertical 7169 feet Effective depth: measured 12921 feet Junk (measured) true vertical 7169 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" lO cu yds Portland Type 3 114' 114' SURF CASING 2786' 9-5/8" 412 Sx AS m, 525 Sx Class G 2786' 2386' PROD CASING 10065' 7" 116 sX Class G 10065' 7131' OPEN HOLE 2856' 6.125" 12921' OPEN HOLE Perforation depth: measured None RECEivED true vertical None iTubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 9719' MD. i Packers & SSSV (type & measured depth) BAKER 'S-3' PACKER @ 9630' MD. CAMCO BAL-O @ 1836' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: April 11,2001 16. If proposal was verbally approved Oil __X Gas __ Suspended _ Name of approver Date approved Service 17. I her. e.b' y certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Em/in@ 265-1478. Sigr~ed ~/V-,-"~-L~~/~//~ ~ ~ Title: Alpine Production Engineer Date~[/7'''7/~) Michael Erwin Prepared by Sharon Ails up-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tifYintegrityC°mmissi°n_ so representatiVeBoP Test _ may witneSSLocation clearance _ Mechanical Integrity Test _ Subsequent form required 10- L.~ ~-~ ORIGINAL SIGNED b' Approved b¥ order of the Commission D TaylorSeamOt'~ Commissioner Date ,'~' ~/"0 / Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLI CATE Stimulation Procedure Colville River Field CD1-43 Conversion operations will commence following ice road construction on or about April 1,2001. Completion is expected on or about April 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-110 bbl. of DS MudSolv mixed in a 9.2 ppg KCL base fluid in the openhole interval. 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 24 hours. 5. Return the well to production. STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 523' FNL, 3000' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 1343' FSL, 1894' FWL, SEC. 6, T11 N, R5E, UM At effective depth At total depth 1316' FNL, 1527' FEL, Sec. 7, T11N, RSE, UM 5. Type of Well: Development _X Explorato~__ Stratigraphic_ Service__ (asp's 385703, 5975608) (asp's 380378, 597~81) (asp's 381823, 5969594) 6. Datum elevation (DF or KB feet) RKB 36 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-43 9. Permit number / approval number 200-106 / 10. APl number 50-103-20344 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical 12921 feet 7169 feet Effective depth: measured 12921 feet true vertical 7169 feet Casing Length Size CONDUCTOR 121' 16" SURF CASING 2786' 9-5/8" PROD CASING 10065' 7" OPEN HOLE 2856' 6.125" Plugs (measured) Junk (measured) Cemented Measured Depth True vertical Depth lO cu yds Portland Type 3 114' 1 14' 412 SxAS III, 525 Sx Class G 2786' 2386' 116 Sx Class G 10065' 7131' 12921' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Packers & S~SV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 9719' MD. BAKER 'S-3' PACKER @ 9630' MD. CAMCO BAL-O @ 1836' MD. RECEIVED zoo/ 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Prior to well operation 2643 3225 3 Subsequent to operation 2767 3031 14 Casing Pressure Tubing Pressure - 208 2O8 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas m Suspended Service Michael Erwin t Date Prepared by Sharon AI/sul~-Drake 265-4612~ Form 10-404 Rev 06/15/88 · ORi61NAL SUBMIT IN DUPLICATE CD1-43 Description of Work Completed CT Mudsolv Treatment LAID IN 126 BBL MUDSOLV ENZYMEFROM 12,725' TO 9500'. SQUEEZED 10 BBL WHILE POOH. STRAIGHTENED PIPE FROM 9500' TO TD (1ST 3400' OF PIPE IN HOLE). RIH TO TD AT 12,921' MD (12,899' CTM DOWN) WITH FDR TOOL VERY EFFECTIVE IN LAST 300'. [Other Stim, Tag] 4/12/01: FLOWED 302 BBL USING GAS LIFT- 144 BBL DIESEL FOLLOWED BY 158 BBL PRIMARILY CHOCOLATE MIXTURE OF WATER & OIL. VERY LITTLE SEPARATED WATER OR SEDIMENT SEEN. NO FROTHY EMULSIONS SEEN. lob PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR 2, 5 2.00t Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the'volumes disposed into surface casing bY production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the first quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul. Mazzolini Drilling Team Leader PM/skad CC' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel ! SnOdgrass. B. Mordson and M: Cunningham Sharon Allsup-Drake Well Files o o o c~ ProActive Diagnostic Services, Inc. TRANSMITTAL To: AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' doey Burton/Jerry Morgan ProActive Diagnostic Services, inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUE LINE Open Hole I I 1 oc -IO ,, C~ j - ~ 3 ~ ~, J::: E F~ O I Res. Eval. CH 1 ~/" I ~-~' 1 v~ .... Mech. CH Caliper Survey 1 'Rpt Or ........ I Color , , Signed' ~ Print Name: L.,i ~ ~'~,~..., I Date ' RECEIVED MAR 0 7 2001 Alaska Oil & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: txlsmtchomge~memorylog.com Website: O1O101 m q q q o --. 0 ~' o 0 .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas [] Suspended [-"] Abandoned [~ Service [~ 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. LOC..AT~ 200-106 3. Address VI~j~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~ 50-103-20344-00 4. Location of well at surface r ..... -. [ 9. Unit or Lease Name I 523' FNL, 2279' F'WL, Sec. 5, T11N, RSE, UM (ASP: 385703, 5975608) ~ ~,~.:..~ ~ Colville River Unit 1343' FSL, 1894' FWL, Sec. 6, T11N, RSE, UM (ASP: 380378, 5972281)~ .......~- i 0D1-43 At Total Depth ! _..._4;~_~- ....:~ 11. Field and Pool 1321' FNL, 1526' FEL, Sec. 7, T11N, R5E, UM (ASP: 381823, 5969594)"~ ..................... -'; Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. Alpine Oil Pool RKB 36 feetI ADL 25559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions I August 14, 2000 August 27, 2000 August 29, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12921' MD / 7169' ']'VD 12921' MD / 7169' TVD YES [-~ No r-']I 1837, feet MD 1639' 22. Type Electric or Other Logs Run GPJRes 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2786' 12.25" 412 sx AS III, 525 sx Class G 7" 26# L-80 Surface 10065' 8.5" 116 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) 4.5" 9718' 9630' 6.125" OH completion from 10065'-12921' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A NOV ZOO0 A~ O~ & Ga~ Co~. Comm~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. t. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD1-43 Top Alpine 9962' 7114' TD 12921' 7169' Annulus left open - freeze protected with diese 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6034 Signed /l~Lv~ ~ ~ Title Drillin,q Team Leader Date G. C. Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Shut-in, Other-explain. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate "none". Form 10-407 RECEIVED NOV Oil & Gas Co~$. Commission Anchorage Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-43 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:08/14/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20344-00 08/13/00 (D1) TD/TVD: 114/114 SUPV:MIKE WHITELEY MW: 8.7 VISC: 300 PV/YP: 13/104 APIWL: 19.0 ( 114) SPUDDED AT 00:30 HRS -DRILLING AHEAD AT 0600 HRS - 500 Move rig from CD1-22A to CD1-43. NU diverter line and function test. Accept rig @ 1500 hrs. 8/13/00. 08/14/00 (D2) MW: 9.6 VISC: 125 PV/YP: 11/73 APIWL: 20.0 TD/TVD: 2178/1954 (2064) DRILLING AHEAD AT 2540' SUPV:MIKE WHITELEY Pre spud meeting. Drill from 114'-535'. Pump not pumping, attempt to prime pumps, POOH to 110', clean out suctions to mud pumps. Drill from 535'-2178' 08/15/00 (D3) MW: 9.7 VISC: 121 PV/YP: 23/51 APIWL: 13.0 TD/TVD: 2796/2392 ( 618) CEMENTING 9 5/8" CASING. SUPV:MIKE WHITELEY Drill from 2178' to 2796'. Survey. Circ for short trip. Wiper trip from 2796' to 900'. Pump out from 1150'-970' Slight swabbing. RIH no problems. Circ and condition to run surface casing. POOH. PJSM. CBU. Run 9-5/8" casing. 08/16/00 (D4) MW: 9.6 VISC: 40 PV/YP: 11/14 APIWL: 9.0 TD/TVD: 2796/2392 ( 0) TRIPPING IN AT 700' SUPV:MIKE WHITELEY Run 9-5/8" casing. Condition mud for cement job. Pump nut plug spacer. Drop bottom plug. ND diverter. NU BOPE and test. 08/17/00 (D5) MW: 9.6 VISC: 46 PV/YP: 10/21 APIWL: 6.2 TD/TVD: 4082/3305 (1286) DRILLING AHEAD @ 4960' SUPV:LUTRICK / REILLY Surface test MW/), failed. TOOH to C/O. RIH with new MW D, surface test OK. Circ-cond mud. Test 9-5/8" casing to 2500 psi. Kick drill. Drill cement and float equipment and 20' new hole from 2706' to 2816'. Perform FIT to 16 ppg. Drill from 2816' to 3830'. Circ hole CBU. Short trip to shoe. Drill from 3830' to 4082' 08/18/00 (D6) MW: 9.7 VISC: 44 PV/YP: 9/25 APIWL: 5.8 TD/TVD: 6779/5351 (2697) HOLE DEPTH 6947' CLEANING PUMP ~2 CLOGGED SUCTION CH SUPV:LUTRICK / REILLY Drill from 4082' to 5351'. Sweep hole CBU. Short trip to 3830'. Hole looked good. Monitor well, R/~__D~ill from 5351' to 6779' ~EC~ E~VED AJaska Oil & Gas Cons. Commission Anchorage Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/19/00 (D7) MW: 9.6 VISC: 39 PV/YP: 7/19 APIWL: 5.2 TD/TVD: 8846/6507 (2067) TRIPPING OUT AT 5700' FOR BHA #3. SUPV:LUTRICK / REILLY Drill from 6799' to 6874'. Circ hi vis sweep. Check flow. Short trip to 5347'. No problems. Check flow. TIH to 6874' Drill from 6874' to 8846' 08/20/00 (D8) MW: 9.6 VISC: 40 PV/YP: 7/20 APIWL: 5.2 TD/TVD: 9384/6859 ( 538) TRIPPING OUT TO INCREASE MOTOR ANGLE. SUPV:LUTRICK / REILLY drill from 8846' to 9064'. Circ hi vis sweep check flow. TOOH to 7639, pump dry job, TOOH.RIH to shoe. CBU, pump sweep, condition hole @ 9064'. Drill from 9064' to 9384' Fire and spill drill. 08/21/00 (D9) MW: 9.6 VISC: 41 PV/YP: 8/24 APIWL: 4.6 TD/TVD: 9872/7101. (488) WIPER TRIP (TD AT 10,065' / 7130') SUPV:DONALD LUTRICK Drilling from 9384' to 9606'. Circ sweep. POH. RIH. CBU to condition mud. Drilling from 9606' to 9872' 08/22/00 (D10) MW: 9.6 VISC: 42 PV/YP: 8/25 APIWL: 4.4 TD/TVD:10075/7131 (203) CIRC AT 9000' SUPV:DONALD LUTRICK Drilling from 9872' to 10075'. Circ hi vis sweep. Wiper trip to 7600'. No problems. Circ hi vis sweep. Pump slug. RU to run 7" casing. PJSM. RIH w/7" casing. CBU. RIH w/7" casing. 08/23/00 (Dll) MW: 9.6 VISC: 39 PV/YP: 6/17 APIWL: 4.6 TD/TVD:10075/7131 ( 0) DRILL OUT CEMENT. SUPV:DONALD LUTRICK RIH w/7" casing. CBU. Land casing at 10065'. Circ and condition mud. PJSM. Pump cement. Did not bump plug. Floats OK. Install packoff and test to 5000 psi. Test BOPE to 300/3500 psi. 08/24/00 (D12) MW: 9.5 VISC: 38 PV/YP: 8/15 APIWL: 6.2 TD/TVD:10095/7132 ( 20) POH W/ MULES SHOE. RIH W/ DRLG ASSEMBLY. DRILL CEMENT. SUPV:DONALD LUTRICK RIH w/DP. Circ and condition mud. Test casing to 3500 psi. Drill out cement, float equipment and 20' new formation to 10095'. Circ and condition mud. Perform LOT, 11.1 ppg EMW. POH to 9150'. Monitor well. Pump slug. RIH to 10095'. PJSM. Pump cement and displaced with mud to balance plug. POH to 9152'. CBU. Well shut in. Monitor pressure. RECEIVED VOv 000 Date: 10/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/25/00 (D13) MW: 9.2 VISC: 50 PV/YP: 10/24 TD/TVD:10205/7142 ( 110) DRLG HORIZONTAL AT 10,600' SUPV:DONALD LUTRICK APIWL: 4.2 WOC w/well shut in. Bleed off pressure. Pump slug. POH w/muleshoe. RIH to 9317'. Wash from 9317' to TOC at 9693' Drill out cement and 20' new formation to 10115'. Circ and condition mud. Perform LOT 11.8 ppg EMW. PJSM. Displace well to 9.2 ppg Flo pro mud. Drilling from 10115' to 10205' 08/26/00 (D14) MW: 9.2 VISC: 52 PV/YP: 12/25 APIWL: 5.1 TD/TVD:l1797/7152 (1592) DRILLING 6-1/8" HOLE FROM 12200' SUPV:DONALD LUTRICK / DAVID BURLEY Drill from 10205' to 11463' Pumped low/high vis sweep and circ hole clean. Pump out to shoe, monitor well, RIH to 11463', no problems. Drill from 11463' to 11797' 08/27/00 (D15) MW: 9.3 VISC: 49 PV/YP: 12/21 APIWL: 4.6 TD/TVD:12921/7169 (1124) POH W/ 6-1/8" STEERABLE DRILLING ASSEMBLY. SUPV:DONALD LUTRICK / DAVID BURLEY Drill from 11797' to 12921' Pumped low/high vis sweep and circ hole clean, monitor well. Pumped out to 10073', no problems. Circ BU, monitor well. RIH to 12921'. Pumped high vis sweep and circ BU. 08/28/00 (D16) MW: 9.2 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12921/7169 ( 0) POH WITH CASING SCRAPER ASSY. SUPV:DONALD LUTRICK / DAVID BURLEY Circ hole clean. PJSM. Displace hole with 9.2 ppg KC1 brine. Monitor loss. POOH to 11330', spot hi vis LCM pill. Continue POOH to 10063'. Monitor fluid loss. Continue POOH, pump dry job, laying down DP with bad hard banding. RIH to 9877'. Monitor losses. Pump hi vis sweep. Circ BU while rotating and recip. 08/29/00 (D17) MW: 9.6 VISC: 27 PV/YP: 1/ 1 APIWL: 0.0 TD/TVD:12921/7169 ( 0) MOVING RIG SUPV:DONALD LUTRICK / DAVID BURLEY Pump dry job. TOOH to 6800' PJSM. Run 4.5" tubing. Test SSSV to 5000 psi. Continue to run completion. ND BOPE. NU tree and test to 5000 psi. 08/30/00 (D18) MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12921/7169 ( 0) NA SUPV:DONALD LUTRICK / DAVID BURLEY PJSM. Freeze protect well. Secure well. Release rig 0500 hrs. 8/30/00 RECEIVED ANADRILL SCHLUMBERGER Survey report 27-Aug-2000 14:16:48 Page 1 of 6 Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CDI-43 API number ............... : 50-103-20344-00 Engineer ................. : Nutter COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Spud date ................ : 13-Aug-00 Last survey date ......... : 27-Aug-00 Total accepted surveys...: 122 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12921.00 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.63 ft ...... Vertical section origin- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 12-Aug-2000 Magnetic field strength.,: 1147.14 HCNT Magnetic dec (+E/W-) ..... : 25.67 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.14 HCNT Reference Dip ............ : 80,54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Platform reference point--- Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.93 degrees [(c)2000 Anadrill IDEAL ID6_lB_48] Corrections --- Magnetic dec (+E/W-) ..... : 25.66 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.66 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED NOV Al~ka 0il & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 27-Aug-2000 14:16:48 Page 2 of 6 Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 115.00 0.00 0.00 3 175.00 0.50 221.00 4 294.57 1.98 229.93 5 382.97 3.63 223.00 Course length (ft) 0.00 115.00 60.00 119.57 88.40 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 115.00 0.00 0.00 0.00 175.00 0.09 -0.20 -0.17 294.54 0.71 -1.92 -2.09 382.83 1.93 --4.95 -5.17 Total displ (ft) 0.00 0.00 0.26 2.84 7.16 At DLS Srvy Azim (deg/ tool (deg) 100f) type 0.00 0.00 TIP 0.00 0.00 MWD 221.00 0.83 GYR 227.48 1.24 MWD 226.25 1.90 MWD Tool qual type -- -- -- 6-axis 6-axis 6 445.00 5.00 223.00 62.03 7 535.00 7.75 219.00 90.00 · 8 653.24 10.18 224.66 118.24 9 743.05 10.95 228.83 89.81 10 834.03 13.18 219.79 90.98 444.68 3.45 -8.36 -8.36 534.12 7.09 -15.95 -14.85 650.91 13.30 -29.58 -27.21 739.19 17.58 -40.84 -39.21 828.17 23.45 -54.50 -52.36 11.82 21.79 40.19 56.62 75.58 224.97 2.21 GYR 222.95 3.09 GYR 222.61 2.18 MWD 223.84 1.21 MWD 223.85 3.21 MWD 6-axis 6-axis 6-axis 11 923.95 14.65 222.15 89.92 12 1013.76 17.16 222.45 89.81 13 1109.23 20.47 225.20 95.47 14 1204.39 23.50 226.62 95.16 15 1299.76 26.13 227.64 95.37 915.45 31.17 -70.81 -66.55 1001.81 39.43 -89.01 -83.12 1092.17 48.93 -111.17 -104.48 1180.40 58.74 -135.93 -130.08 1266.96 68.94 -163.15' -159.42 97.18 121.78 152.56 188.14 228.11 223,22 1.75 MWD 223.04 2.80 MWD 223.22 3.59 MWD 223.74 3.23 MWD 224.34 2.79 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 16 1393.74 29.09 228.54 93.98 17 1490.47 31.84 229.33 96.73 18 1585.35 34.43 229.97 94.88 19 1680.73 36.48 232.01 95.38 20 1776.18 39.11 230.68 95.45 21 1870.68 42.30 231.83 94.50 22 1965.80 45.47 234.70 95.12 23 2059.16 46.07 235.48 93.36 24 2151.73 45.71 236.39 92.57 25 2250.24 45.40 237.08 98.51 1350.23 79.34 -192.22 -191.84 1433.59 90.36 -224.43 -228.82 1513.04 101.38 -257.99 -268.35 1590.73 111.85 -292.80 -311.35 1666.15 122.61 -329.34 -357.01 1737.78 134.01 -367.89 -405.08 1806.33 143.89 -407.28 -457.94 1871.46 151.86 -445.56 -512.80 1935.89 158.80 -482.79 -567.85 2004.87 165.17 -521.37 -626.66 271.58 320.51 372.25 427.40 485.72 547.21 612.85 679.33 745.35 815.18 224.94 3.18 MWD 225.56 2.87 MWD 226.13 2.75 MWD 226.76 2.48 MWD 227.31 2.88 MWD 227.75 3.47 MWD 228.35 3.93 MWD 229.01 0.88 MWD 229.63 0.81 MWD 230.24 0.59 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 26 2346.33 45.12 236.25 96.09 27 2443.11 44.41 235.31 96.78 28 2536.16 43.97 235.48 93.05 29 2630.25 45.00 236.26 94.09 30 2735.75 44.54 235.59 105.50 [(c)2000 Anadrill IDEAL ID6_lB_48] 2072.51 171.43 -558.87 -683.68 2141.22 178.73 -597.20 -740.04 2207.94 186.11 -634.03 -793.42 2275.07 193.07 -671.02 -848.00 2349.97 200.84~ -712.65 -909.54 RECEIVED NOV Z 2000 883.04 950.95 1015.63 1081.37 1155.48 230.74 0.68 MWD 231.10 1.00 MWD 231.37 0.49 MWD 231.65 1.24 MWD 231.92 0.62 MWD 6-axis 6-axis 6-axis 6-axis 6-axis Al~k~ Oil & Ges Cons. Commi~on ANADRILL SCHLUMBERGER Survey Report 27-Aug-2000 14:16:48 Page 3 of 6 Seq Measured Incl Azimuth $ depth angle angle - (ft) (deg) (deg) 31 3005.56 43.20 235.21 32 3291.68 45.38 232.59 33 3575.56 45.58 231.78 34 3861.26 45.37 230.67 35 4147.30 43.93 231.90 36 4431.55 45.71 233.57 37 4717.32 45.67 233.07 38 5001.85 45.58 232.04 39 5287.90 46.06 234.03 40 5573.66 44.76 234.02 Course length (ft) 269.81 286.12 283.88 285.70 286.04 284.25 285.77 284.53 286.05 285.76 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 2544.47 2749.29 2948.33 3148.67 3352.17 3553.79 3753.41 3952.40 4151.78 4352.41 222.09 -818.82 -1063.45 250.08 -936.58 -1224.79 284.35 -1060.68 -1384.69 322.18 -1188.23 -1543.49 359.33 -1313.97 -1700.31 391.30 -1435.24 -1859.78 421.92 -1557.39 -2023.77 455.04 -1681.04 -2185.24 486.74 -1804.36 -2349.12 514.73 -1923.90 -2513.80 1342.16 1541.85 1744.25 1947.88 2148.86 Srvy tool type 2349.19 2553.65 2757.02 2962.11 3165.53 232.41 0.51 MWD 232.60 0.99 MWD 232.55 0.22 MWD 232.41 0.29 MWD 232.30 0.59 MWD 232.34 0.75 MWD 232.42 0.13 MWD 232.43 0.26 MWD 232.47 0.53 MWD 232.57 0.45 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 41 5859.89 45.67 235.45 42 6145.69 44.88 233.95 43 6242.08 47.19 235.74 44 6336.18 48.23 239.46 45 6431.63 '49.11 244.16 46 6526.33 49.84 252.43 47 6621.44 50.42 255.59 48 6716.16 50.36 255.05 49 6807.24 50.80 254.24 50 6905.69 50.93 254.04 51 7001.60 50.79 251.31 52 7191.56 50.79 250.86 53 7381.83 50.62 249.64 54 7572.61 49.85 249.83 55 7762.29 48.75 248.83 286.23 285.80 96.39 94.10 95.45 94.70 95.11 94.72 91.08 98.45 95.91 189.96 190.27 190.78 189.68 4554.04 4755.17 4822.08 4885.41 4948.47 5010 06 5071.04 5131.43 5189.27 5251.40 5311.95 5432.04 5552.54 5674.57 5798.26 540.15 -2041.17 -2679.67 565.69 -2158.48 -2845.39 574.22 -2198.41 -2902.12 579.45 -2235.68 -2960.88 579.59 -2269.50 -3024.03 571.59 -2296.05 -3090.82 556.31 -2316.15 -3160.97 539.41 -2334.64 -3231.56 523.93 -2353.27 -3299.41 507.77 -2374.14 -3372.87 493.91 -2396.29 -3443.87 470.49 -2444.00 -3583.11 449.18 -2493.76 -3721.69 429.27 -2544.55 -3859.26 410.73 -2595.30 -3993.81 3368.53 3571.46 3640.78 3710.13 3780.93 3850.32 3918.71 3986.67 4052.65 4124.66 4195.53 4337.26 4479.93 4622.62 4762.99 232.70 0.48 MWD 232.82 0.46 MWD 232.86 2.74 MWD 232.94 3.13 MWD 233.11 3.81 MWD 233.39 6.68 MWD 233.77 2.62 MWD 234.15 0.44 MWD 234.50 0.84 MWD 234.86 0.21 MWD 235.17 2.21 MWD 235.70 0.18 MWD 236.18 0.50 MWD 236.60 0.41 MWD 236.98 0.70 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 56 7954.24 49.66 248.75 191.95 57 8145.45 49.53 250.55 191.21 58 8334.61 49.72 250.27 189.16 59 8524.90 48.69 249.57 190.29 60 8715.28 48.33 249.50 190.38 5923.67 393.38 -2647.87 -4129.28 6047.62 373.82 -2698o50 -4265.78 6170.15 352.57 -2746.82 -4401.54 6294.48 332.54 -2796.27 -4536.85 4905.32 5047.65 5188.32 5329.36 5469.33 237.33 0.48 MWD 237.68 0.72 MWD 238.03 0.15 MWD 238.35 0.61 MWD 238.64 0.19 MWD 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_lB_48] NOV 2 2 ZOO0 Naska Oil & Gas Cons. ANADRILL SCHLUMBERGER Survey Report 27-Aug-2000 14:16:48 Page 4 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 8905.76 48.06 249.57 190.48 62 8997.02 47.86 249.00 91.26 63 9090.86 48.40 251.89 93.84 64 9185.56 49.95 253.21 94.70 65 9217.61 49.38 248.41 32.05 66 9249.87 50.03 243.89 67 9280.50 50.65 240.64 68 9312.95 51.30 237.41 69 9344.97 52.08 233.61 70 9376.15 52.30 230oll 32.26 30.63 32.45 32.02 31o18 TVD depth (ft) 6547.57 6608.69 6671.33 6733.24 6753.99 6774.86 6794.41 6814.85 6834.70 6853.82 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 294.88 -2895.78 -4803.48 5608.83 286.20 -2919.75 -4866.87 5675.51 275.86 -2943.14 -4932.71 5744.01 262.65 -2964.62 -5001.07 5813.75 258.87 -2972.64 -5024.13 5837.68 257.07 -2982.59 -5046.62 256.93 -2993.56 -5067.49 258.21 -3006.54 -5089.09 261.03 -3020.76 -5109.79 265.33 -3035.97 -5129~16 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 5862.10 5885.65 5910.85 5935.91 5960.32 238.92 0.14 MWD 239.04 0.51 MWD 239.18 2.36 MWD 239.34 1.95 MWD 239.39 11.55 MWD 239.42 10.87 239.43 8.41 239.43 7.99 239.41 9.62 239.38 8.90 6-axis 6-axis -- -- -- 71 9408.44 52.45 226.34 32.29 6873.53 72 9440.28 52.95 223.11 31.84 6892.83 73 9471.87 53.20 219.31 31.59 6911.81 74 9503.81 54.23 215.96 31.94 6930.72 75 9535.60 54.98 212.66 31.79 6949.14 271.39 -3053.01 -5148.23 5985.41 278.88 -3071.00 -5166.05 6009.92 287.82 -3089.99 -5182.68 6033.92 298.41 -3110.38 -5198.39 6057.86 310.42 -3131.78 -5212.99 6081.39 239.33 9.26 MWD 239.27 8.22 MWD 239.20 9.65 MWD 239.11 9.04 MW/3 239.00 8.78 MWD 76 9566.47 56.03 209.24 30.87 6966.63 77 9599.57 57.19 205.59 33.10 6984.85 78 9631.12 58.57 201.69 31.55 7001.63 79 9662.16 60.03 197.68 31.04 7017.48 80 9693.96 62.01 193.00 31.80 7032.90 81 9725.85 63.94 189.12 31.89 82 9756.81 66.04 185.83 30.96 83 9789.20 69.97 181.72 32.39 84 9820.63 73.26 177.49 31.43 85 9852.13 75.39 174.40 31.49 323.52 -3153.59 -5226.07 6103.84 339.18 -3178.12 -5238.78 6127.42 355.74 -3202.60 -5249.49 6149.29 373.68 -3227.72 -5258.47 6170.06 393.89 -3254.54 -5265.81 6190.38 7047.39 415.92 -3282.41 -5271.25 6209.70 7060.48 438.75 -3310.22 -5274.90 6227.53 7072.61 464.26 -3340.18 -5276.86 6245.16 7082.53 490.67 -3369.99 -5276.64 6260.97 7091.04 518.36 -3400.23 -5274.49 6275.49 238.89 9.75 MWD 238.76 9.85 MWD 238.61 11.35 MWD 238.46 12.06 MWD 238.28 14.30 MWD 238.09 12.41 237.89 11.78 237.67 16.90 237.44 16.51 237.19 11.62 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 86 9884.77 76.57 170.03 32.65 87 9916.77 77.15 167.84 32.00 88 9947.96 77.77 164.05 31.19 89 9979.89 79.11 160.20 31.93 90 10006.07 81.00 156.89 26.18 7098.95 548.06 -3431.60 -5270.20 6288.95 7106.23 577.86 -3462.18 -5264.22 6300.69 7113.00 607.39 -3491.71 -5256.83 6310.81 7119.40 638.17 -3521.48 -5247.22 6319.35 ~-~-~9~-,, ,,~8 -3545.47 -5237.79 6324.94 236.93 13.48 236.67 6.91 236.41 12.03 236.13 12.54 235.91 14.39 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6_lB_48] NOV ; 000 Alaska Oil & Gas Cons. ANADRILL SCHLUMBERGER Survey Report 27-Aug-2000 14:16:48 Page 5 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 91 10114.32 85.60 147.86 108.25 7136.58 771.15 -3640.58 -5187.97 6337.89 234.94 9.31 92 10206.04 87.36 149.40 91.72 7142.21 862.54 -3718.74 -5140.32 6344.44 234.12 2.55 93 10297.94 88.97 149.84 91.90 7145.15 954.31 -3797.98 -5093.87 6353.91 233.29 1.82 94 10392.66 89.49 149.99 94.72 7146.42 1048.97 -3879.93 -5046.39 6365.53 232.45 0.57 95 10483.50 89.79 151.42 90.84 7146.99 1139.78 -3959.15 -5001.95 6379.21 231.64 1.61 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 96 10574.77 90.27 151.61 91.27 7146.95 1231.05 -4039.37 -4958.42 6395.50 230.83 0.57 97 10667.77 89.45 149.40 93.00 7147.17 1324.01 -4120.31 -4912.63 6411.78 230.01 2.53 98 10760.17 89.79 149.04 92.40 7147.79 1416.31 -4199.69 -4865.35 6427.21 229.20 0.54 99 10852.38 90.03 149.97 92.21 7147.93 1508.43 -4279.15 -4818.55 6444.34 228.39 1.04 100 10943.36 90.34 151.26 90.98 7147.64 1599.39 -4358.42 -4773.91 6464.22 227.61 1.46 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 101 11037.44 89.25 150.69 94.08 7147.97 1693.45 -4440.68 -4728.27 6486.62 226.80 1.31 102 11130.98 89.73 150.60 93.54 7148.81 1786.96 -4522.21 -4682.42 6509.64 226.00 0.52 103 11223.97 90.07 150.82 92.99 7148.97 1879.93 -4603.31 -4636.92 6533.87 225.21 0.44 104 11316.05 90.41 150.54 92.08 7148.58 1971.99 -4683.59 -4591.83 6559.04 224.43 0.48 105 11405.34 89.42 149.96 89.29 7148.72 2061.24 -4761.11 -4547.53 6583.93 223.69 1.29 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 106 11500.30 90.10 149.66 94.96 7149.11 2156.13 -4843.19 -4499.77 6610.94 222.89 0.78 107 11595.33 88.77 150.19 95.03 7150.05 2251.10 -4925.42 -4452.16 6639.39 222.11 1.51 108 11686.17 89.31 150.12 90.84 7151.57 2341.88 -5004.20 -4406.96 6668.08 221.37 0.60 109 11778.32 88.63 149.56 92.15 7153.23 2433.95 -5083.86 -4360.67 6697.84 220.62 0.96 110 11870.91 87.77 149.72 92.59 7156.14 2526.42 -5163.72 -4313.89 6728.57 219.88 0.94 111 11962.00 88.11 149.55 91.09 7159.41 2617.38 -5242.26 -4267.87 6759.89 219.15 0.42 112 12054.13 88.53 149.46 92.13 7162.11 2709.39 -5321.61 -4221.14 6792.47 218.42 0.47 113 12145.24 89.31 149.69 91.11 7163.83 2800.40 -5400.16 -4175.01 6825.87 217.71 0.89 114 12236.58 89.93 149.41 91.34 7164.44 2891.66 -5478.90 -4128.72 6860.37 217.00 0.74 115 12330.78 88.70 150.02 94.20' 7165.56 2985.78 -5560.24 -4081.22 6897.29 216.28 1.46 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 116 12422.52 89.18 150.21 91.74 7167.26 3077.46 -5639.76 -4035.52 6934.87 215.59 0.56 117 12515.31 89.62 150.20 92.79 7168.23 3170.20 -5720.28 -3989.42 6974.03 214.89 0.47 118 12608.02 90.14 150.69 92.71 7168.43 3262.88 -5800.93 -3943.69 7014.52 214.21 0.77 119 12701.80 89.31 150.72 93.78 7168.88 3356.64 -5882.71 -3897.80 7056.85 213.53 0.89 [(c)2000 Anadrill IDEAL ID6_lB_48] NO¥ S S ZOO0 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6--axis Alaska Oil & Gas Cons. ANADRILL SCHLUMBERGER Survey Report 27-Aug-2000 14:16:48 Page 6 of 6 Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) · 121 12863.50 90.21 149.61 68.94 7169.45 F£nal Surve~ Pro~ected to bit 122 12921.00 90.21 149.61 57.50 7169~24 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 3518~24 -6022.73 -3816.92 3575.69 -6072.33 -3787.84 7130.37 212.36 7156.88 211.96 0.48 0.00 IMP 6-axis Projection [(c)2000 Anadrill IDEAL ID6_lB_48] RECEIVED NOV PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 nnr 9 2000 Dear Ms. Mahan: ~'~ '"~ ~" Please find repomed below the volumes injected into surface casing bY~?~uction casing annuli during the third queer of 2000, as well as tot~ volumes injected into annuli for which injection authorization expired during the third queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Totaifor Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990- 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 q'l- I~I ~o- o b3 Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: ~Fotal ~ ' Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD 1-23 33886 100 0 33986 Open, Free ze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas ConserVation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find repOrted below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection durin$ the third quarter of 2000: h(1)' h(2') ~(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 /_-'~ CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 ~ CD1-25 24860 100 0 24960 8627. 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 ~9- oo 1. Type of request: r STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 .Anchorage, AK 99510-0360 4. Location of well at surface 523' FNL, 2279' FWL, Sec.5, T11N, R5E, UM At target (7" casing point in Alpine)) 1143' FNL, 2018' FWL, Sec 6, T11 N, R5E, UM At effective depth At total depth 1337' FNL, 1569' FEL, Sec.7, T11 N, R5E, UM ...... Plugging _ Time extension _ Stimulate _ Other_ Pull tubing _ Variance _ Perforate _ Annular Injection - X 5. Type of Well: Development __X Exploratory _ Stratigraphic _ Service __ per APD per APD 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CDI-Se- 9. Permit number / approval number 200-t.ee ~ Io1,,, 10. APl number 50-103-20344-00 11. Field / Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 12921 feet true vertical 7169 feet Effective depth: measured 12921 feet true vertical 7169 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2749' 9.625" 525 sx ASL3, 412 sx Class G 2786' 2386' Production 10030' 7" 116 sx Class G 10065' 7130' CD1-43 is as an open hole production well. It was suspended after being completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. ORIGINAL RECEIVED SEP 1 4 000 Aiaska 0if & Gas Cons. Commis~ 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch __ 14. Estimated date for commencing operation 115. Status of well classification as: I November 15, 2000 16. If proposal was verbally approved IOil ~X Gas __ I Name of approver Date approved JService __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended__ Title: Drilling Team Leader Date ~/iZ_/~'~o FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10-/'~ ~ ,~ I Appr°va' n°j ~"~, c~,~/ Approved by order of the Commission ORIGINAL SIGNED BY D Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 12, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-43 Dear Sirs: Phillips Alaska, Inc. hereby requests that CD1-43 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: . 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-43 Well Completion Schematic. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Sit, rely, ~ Scott D. Reynolds Drilling Engineer CC. CD1-43 Well File Alpine Files Chip Alvord Gracie Stefanescu ANO-382 Anadarko RECEIVED SEP 14 Ataska 0~; & Gas Co[~s. ~.mmissio~ Anchorage Casing Detail 9 5/8" Surface Casing Well: CD1-43 Date: 8/15~00 'PHILLIP$ Alaska, Inc. ~ A :~UDSidEffy or PHILLIPS PETROLEUM COIvlPANT DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.42 FMC Gen V Hanger 2.51 36.42 Jts 3 to 73 71 Jts 9-5/8" 36# J-55 BTC Csg 2667.59 38.93 Davis Lynch Float Collar 1.48 2706.52 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 76.33 2708.00 Davis Lynch Float Shoe 1.77 2784,33 2786.10 TD 12 1/4" Surface Hole RUN TOTAL 42 BOWSPRING CENTRALIZERS - I per it on Jt #1 - #13 (On stop rings of Jt #1 & ~2) and over collars on jts# 15,17,19,21,23,25,27,29,31 33,35,37,39,41,43,45,47,49,51,53,55,57,59,61,63,65, 67,69, 71. 14 2OO0 A~0m0e Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 160k Dn Wt - 130k Block Wt - 70k ,,, Supe~isor: MIKE WHITELEY Phillips Alaska Drilling Cementing Details Well Name: CD1-43 Report Date: 08/15/2000 Report Number:. 3 Ri~l Name: Doyen 19 AFC No.: 998C10 Field: COLVlLLE ... Centralizers State type used, intervals covered and spacing Comments: TOTAL OF 42 BOWSPRINGS. I PER JOINT ON JTS 1-13. STOP RINGS ON 1 & 2. I EVERY OTHER JT ON JTS 15-71. 42 BOW SPRING " Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 23 16 51 17 Gels before: Gels after: Total Volume Circulated: 32/61/77 5/29/38 1200 BBLS Wash 0 Type: Volume: Weight: Comments: Water 40 8.4 40 BBL HIGH VIS NUTPLUG · Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 10.5 · Lead.cement 0 ' Type: I Mix wtr temp: No. of Sacks: Weight: Yield: I comments: ASlII 70 412 10.6 4.44 · · : : :Additives: : . 30% D053, 0.6% D046, 1.5% D079, 1.5% S001, 50% D124, 9% BWOW D044. I I Tail:Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: co~m;ents:. 70 525 10.7 1.15 : G : · Additives: , : . · .' 0.2% D046, 0.3% D065, 1% S001 Di~Placemellt i 0 : Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: c0mmentsi 8.8 8.8 160 ~ := ~. ~.. = : Reciprocation length: Reciprocation speed: Str. Wt. Down: · 20 10FPM 130 . Theoretical Displacement: Actual Displacement: Str. Wt. in mud: ~ : = :,, :: ·: 212 212 Calculated top of cement: CP: Bumped plug: Floats held: SURFACE Date:8/16/00 YES YES Time:0600 Remarks:REClP. PIPE THROUGHOUT JOB, ClRC 150 BBL 10,6 SLURY TO SURFACE, CEMENT STOOD AT SURFACE. Cement Company: Rig Contractor: Dowell DOYEN Approved By: MIKE WHITELEY RECEIVED SEP '1 4 2000 Alaska O~i & Gas Cons. Commission Anchorage Phillips Alaska Drilling Daily Drilling Report I Date Rpt No ti Rig Accept - hrs Days Since Accept/Est: 3.35 / 3.5 AFC No. 998C10 108/16/2000 4 106/13/2000 03:00:00 Rig Relase - hrs: IPM Well: CD1-43 Depth (MD/TVD) 2796/2392 Prev Depth MD: 2796 Progress: 0 Contractor: DOYON Daily Cost $ 324608 Cum Cost $ 666115 Est Cost To Date $ 625000 Rig Name: Doyon 19 Last Cs~: 9 5/8' @ 2786 Next Cs~: 7" @ 10054'. Shoe Test: Operation At 0600: TRIPPING IN AT 700'. Upcoming Operations: CASING TEST. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL LSND 2796 N TST 06/09/2000 06/1 6/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL '9.6ppg 06/09/2000 06/09/2000 VISCOSITY PU WI' MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 40sqc 150 N SPACE 08/08/2000 06/21/2000 PV/YP SO WT TYPE TYPE TYPE 11 / 14 135 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 1345 5/6/8 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 830 9.0 08/15~2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 121 NCml/30 Tin USED- BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL : :W~HER~i:~ :i 5.5% CD1-25 HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 45 215bbl 52O111 / / CD1-43 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 8 10.0 I 121 I 4 )h LINER SZ RPM I RPM 1 PRESSURE (psi) WIND DIRECTION 180° 8 s.s 16.01 I 1298 LGS SPM 1 TFA TEA INJECTION FLUIDS CHILL FACTOR °F 37.18 0.3% 8o111 Water Base Muds 2067 PIT VOL GPM 2 JETS JETS Diesel PHILLIPS 4 75 III 11111 IIIII 60 PERSONNEL Cement 150 DAILY MUD SPS 1 BIT COST BIT COST Fresh Water CONTRACTOR 28 $10077 III 240 PERSONNEL Brine 63 TOTAL MUD I SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5: $27846 III III III 2880 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI 9.6111 III III 33587 PERSONNEL TOTAL 53 :1 MILL TOOTH BIT, MAVlDRILL MACH lC AKO - 1.5 DEG, SHOR NM DC, NM STAB, MWD, UBHO SUB, 2 - 8" OD NM DC'S, NM STAB, 11- 8" NM DC, XO, 3JTS- 5" HWDP, JARS, 26JTS - 5" HWDP BHA NO 1 OD WEIGHT:: ; GRADE ~: i:: ::CONNEcTiaN:~ CEA;SS!2 :: EENG~H ~i BHA LENGTH 1080.6 5 4.281 19.5 G105 4-1/2 I.F. PREM DATE LAST INSPECTED: HOURS ON JARS: 12:00 AM 01:00 AM 1.00 CASG SURF Casing and RUN 9 518" CSG. Cementing 01:00 AM 04:00 AM 3.00 CIRC SURF Casing and COND. HOLE FOR CEMENT JOB. Cementing 04:00 AM 06:30 AM 2.50 CASG SURF Casing and PUMP 40 BBL NUTPLUG SPACER - 5 BBL H20 - TEST Cementing LINES T/2500 PSI - DROP BTM PLUG - ClP @ 0600 - CHECK FLOATS. 06:30 AM 07:30 AM 1.00 CASG SURF Casing and REMOVE L/J - CMT HEAD - BALES - ELEV. Cementing 07:30 AM 08:00 AM 0,50 PREP SURF Other M/U JT OF DP AND STACK WASHER SUB - WASH STACK. 08:00 AM 09:30 AM 1.50 NU_ND SURF Other N/D DIVERTER. 09:30 AM 10:00 AM 0.50 NU_ND SURF Other INSTALL CASING HEAD - TEST SEAL T/1000 PSI. 10:00 AM 11:30 AM 1.50 NU_ND SURF Other N/U BOPE. Daily Drilling Report: CD1-43 08/16/2000 Page 1 11:30 AM 12:00 PM 0.50 PREP 12:00 PM 04:30 PM 4.50 BOPE 04:30 PM 05:00 PM 0.50 PREP 05:00 PM 05:30 PM 0.50 PREP 05:30 PM 06:30 PM 1.00 BHA 06:30 PM 08:30 PM 2.00 PREP 08:30 PM 09:30 PM 1.00 RIGS 09:30 PM 11:30 PM 2.00 PREP 11:30 PM 12:00 AM 0.50 PREP 24.00 SURF SURF SURF SURF SURF SURF SURF SURF SURF Other Other Other Other Other Other Other Other Other PJU TO TEST BOPE TEST BOPE. SET WEAR RING. P/U HANDLING TOOLS AND BALES. P/U BIT - FLOATS - AND BIT SUB. P/U 82 JTS DP. CUT AND SLIP 120' DRLG LINE. POOH. P/U DP. Supervisor: LUTRICK/REILLY RECEIVED SEP 14 2000 Alaska Oi.; & Gas Cons. CommJss~ Anchorage Daily Drilling Report: CD1-43 08/16/2000 Page 2 i,-- i i i ! ! ~, ! ! ! .--.--.--.--.--.--....-..............................-....... 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I ~ ;I z z z iI Colville River Field CD1-43 Production Well Completion Plan ~i~ " 14' 16 Conductor to 1 !~iii 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID)at 1700'.TVD iii!ilj : ,~uOla;ti~;,,Sxle0e.;~o,W,i~sDcBo-n6troNiO;inG;sLOCk (3.812 OD) :,!!iiI~ii9-5/8 36 ppf J-55 B C ~ Surface Casing 2786' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 4216' MD / 3400' TVD for E Dummy with 1" BK-2 Latch Updated 9/12/00 = 1837' MD run in profile WRDP-2 SSSV (2.125"1D) w/DB- 6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet lube pipe dope Completion Tubing Supended with diesel to lowest GLM MD 32' 1837' 4216' 6827' 9520' 9578' 9630' 9706' Camco KBG-2 GLM (3.909" ID) at 6827' MD / 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear ¢~ +/- 2000 psi set 1 oint above the X landing nipple Tubing 4-1/2", Camco 4-1/2", Camco 4-1/2", Camco 4-1/2", Hanger 12.6#/ft, IBT-Mod Tubing BAL-O SSSV Nipple 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joint (1) HES "X" (3.813" ID) 4-1/2" tubing joint (1) S3 Packer (c/w handling pups) 4-1/2" tubing joint (1) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 63 deg) 046' TVD 32' 1700' 3400' 5200' 6940' 6973' 7002' 7038' 9719' Baker S3 Packer at +/- 9636' TOC @ +/- 9462' MD (+500' MD above top Alpine) Top Alpine at 9962' MD ! 7114' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 10065' MD / 7130' TVD @ 87 deg Well TD at 12921' MD / 7169' TVD 4J 0 0 m >,ir0 o ,.--t OE~ U~ 0 I I I I I ~E~ 0 0 0 -,q 0 G · 0 O~ 0 0 0 0 OO ~o0 oo ~u~Q~ oo ~--I ~--~ (D · · 4J 4J 4J U · o o o o,I II ~> 0 ~ II h O :>~ II II II ~---- II II r.o U~ II II ~ ~)o II II E~ ~ o II ..... 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O0 0 0 0 0 ,--I Lr~ 04 ,.--I 0 O0 ,-"1 "~::~ ['~ 0 04 0oomooo ~ 00~ 0'~ O0 O0 I I I I II O H rd ~ II 0~ II ~) =~= I II Oa t'~ 0 0 ,--too kO "m:~ 00~ o,,1 ~-I ~.--I ,--t H ,-i 0 0'1 0'~ 0 0 O~ O0 CO 0'~ 0"~ 0 0 0 0 0 ,--I ~---t ,--I ,--I ,--I O~ O~ O~ 0'~ 0 0 L~ 0'~ 0 (',,} 0 0 0 0 0'~ 0~ O~ 0 0 0'~ O0 O00~ 0'1 O0 O~ O O o~ O~ 0 r--I ,--I 0'~ 04 0 {'~ ,,~1~ CO cO o~ 0 ,--I 0,1 c~} u'~ ¢,'"') 000 I.~ k.O f'~ oo O~ 0 -,-I II II II ,--t ,---{ ~ II m II o ~ ~ II -,-t II o ~ :>1 II :x: II E~ ~-iJ II ~ II I1 I II ~> o ~ II ~ II ~ o :>. II ~.. II II ,,..o II '~ ~ II II o3 ~u,-i II u,.q II ~ (}.)o II '~ O It E~ ~ o II · II ~ ,-I II o o u II II II I~ ~ II II 4J-H ~ II m II ~ N (i.) II I1 ~ "'O II eq II ~ II ~ II II cq 11 II 11 II II ~ ~ .,-- II II · ~J,.J II m II J,J m ~ II II o-,-I ~ II o II H "O II m II II II ,..c: II L~ II ~ ~ -'-'- II ~ II :::> E)~ 4J II II ~ II ',-'~ II ~ ~ II ~:) II II r-- 0 o o ,r.---i (~1 MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Well No CD1-43 Installation/Rig Doyen 19 Dispatched To: AOGCC Date Dispatche 6-Sep-00 Dispatched By: Nathan Rose LOG Run No. Scale Odginal Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 R CE!VI=D ~EP 1 ~ ~.01~0 A~ska C ~ & Gas Co.~s. ~ ~mmissk~ A~c~orage Received By: Q~~.~~/._~..a..~~,x.j~ N~ please sign and return to: Anadrill [.W~ DMsion 3040 Arctic BlYd, Suite 300 Anchorage, Alaska 99503 rose@anchorage.anaddll.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner c;~v//~ 0 THRU: Blair Wondzell P.I. Supervisor FROM: John Crisp J~,~ Petroleum Inspector NON- CONFIDENTIAL DATE: 8/23/2000 SUBJECT: Blowout Preventer Test Doyon 19 Phillips Alaska Alpine CD1-43 200-106 Colville River Unit Operator Rep.: Donnie Lutrick Contractor Rep.: Ron Matthesson Op. phone: 659-3000 Rig phone: 670-4727 Op. E-Mail: Rig E-Maih Test Pressures Rams: 3500 Annular: 2500 Choke: ,3500 TEST DATA MlSC, INSPECTIONS: FLOOR VALVES: P/F P/F Quantity P/F Location Gen.: Good Sign: Yes Upper Kelly 1 P Housekeeping: Good Rig cond: Good Lower Kelly 1 P PTD On Location Yes Hazard: Yes , Ball Type 1 P Standing Order: Yes , Inside BOP 1 P BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8" P Pipe Rams 1 3 1/2x6" P Lower Pipe Rams 1 3 1/2x6" P Blind Rams 1 13 5/8" P Choke Ln. Valves 1 4 1/16" P HCR Valves 1 4 1/16" P Kill Line Valves 1 4 1/16" P Check Valve CHOKE MANIFOLD: Quantity P/F No. Valves 16 P Man. Chokes 1 Functioned Hyd. Chokes 1 Functioned MUD SYSTEM: Visual Alarm Trip Tank Yes Yes Pit Level Indicators Yes Yes Flow Indicator Yes Yes Meth Gas Detector Tested Tested H2S Gas Detector Tested Tested ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 After Closure 1500 200 psi Attained 28 sec. Full Pressure 3 min. 17 sec. Blind Covers (All Stations): Yes N2 Bottles (avg): 6 btls 1825 ave. Test's Details I traveled to Phillip's Alaska's Alpine Field in the Colville River Unit to witness the weekly BOP test on Doyon 19. Testing went very well with no failures witnessed. Total Test Time: 3.5 hrs. umber of Failures: CC: Attatchments: _0 Sheet by L.G. 3/18/00 V01 i28uu.xls 8/30/00 ALASKA OIL AND GAS Doug Chester CONSERVATION COPlPllSSION Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Colville River Unit CD 1-43 Phillips Alaska, Inc. Permit No: 200-106 Sur Loc: 523'FNL, 2279'FWL, Sec. 5, T1 IN, R5E, UM Btmhole Loc. 1337'FNL, 1569'FEL, Sec. 7, T1 IN, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Since Phillips has been unable to identify the source of the diesel fumes encountered in nearby offset wells, a mud log will be required for the surface hole section of this well,. 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / ~ day of August, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. ' 'Type 0i"~)rk Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen[ Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 523' FNL, 2279' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1143' FSL, 2018' FWL, Sec. 6, T11 N, R5E, UM CD1-43 #U-630610 At total depth 9. Approximate spud date Amount 1337' FNL, 1569' FEL, Sec. 7, T11 N, R5E, UM 08/05/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 42 12,865' MD Crosses Sec. 5 to feet 9.4' @ 313' Feet 2560 7,170' TVD feet Sec 7 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 89° Maximum surface 2526 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Len~lth MD TVD MD TVD /include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2776' 37' 37' 2813' 2400' 534 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 10017' 37' 37' 10054' 7128' 116 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9604' 32' 32' 9636' 7005' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 'i'~e°;dr?ce,idi°ante0R I61NAL Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid;~ogram X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby ce~f~ that the foregoing is true and correct to the best of my knowledge Signed . , .- ,...., .~ Title Drilling Team Leader Date v /,~/' v - Commission Use Only (See cover letter for Perm~r....~)6 IAPl ~De'~50' "~--~-~ VV--~)0 IAppr°Va, date {~I i I r)0O,,er requirements Conditions of approval Samples required Yes ~ Mud I~g{req~ir~'d Hydrogen sulfide measures Yes ('~ Directional survey required (~ No Required working pressure for BOPE 2M 3M 5~ 10M 15M Other: '4o.~C:)~ ~'~(~'t~:> .~..%~- ~-~_.%%,,..~--~.. by order of Approved by ORIGINAL SIGNED BY Commissioner the commission Date Form 10-401 Rev. 7-24-89 D Taylor Seamount i -" Jbl'nit in triplicate Alpine: CD1-43 Procedure 1. . 3. 4. 5. 6. 7. 8. , 11. 12. 13. 14. 15. 16. 17. 18. 19. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency- set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 Y2, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus Set BPV and secure well. Move rig off. JUL 1 2 2000 A ' lasKa Oii& Ga~ Co~s, Commi~[on Anchorage Well Proximity Risks:(: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-42 will be the closest well to CD1-43 (9.4' at 313' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.7' at 338' MD. Drillin.q Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Diesel odors have been encountered while drilling out of the surface casing shoe in nearby offset wells. Proper PPE will be on hand to cover this eventuality. Lost circulation: There is some potential for lost circulation in the Alpine sand. If losses are encountered, conventional LCM treatments will be used. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations on well CD1-43 will be injected into the annulus of a permitted well. The CD1-43 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-43 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi -- (12.0 ppg) * (0.052) * (2400') + 1,500 psi ~ ........ ~' ~': "',~,.~ ~,, ~;;;,.. ~ · ,~ ,,~,~,~, ;? ~,?' ,. = 2,998 psi Pore Pressure = 1,086 psi JUL 1 2 2000 Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-43 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 1~,, Section - 6 1/8" point- 12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. JUL 1 2 2000 Oii& Cons. Commission Anchor~e Colville River Field CD1-43 Production Well Completion Plan 16" Conductor to 114' Updated 07/06/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD = 1825' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2813' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel Oep 4-1/2" 12.6 ppf L-80 IBT Mod. R_~.3 tubing run with Jet lube pipe dope Tubing Suoended with diesel to lowest GLM Completion MD TVD TOC @ +/- 9400' MD (+500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch JUL 1 2 2000 AJaskaOii& -' ..... ~., Anchor, s Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear ~ +/- 2000 psi i~]~above the X landing nipple "~.. Baker S3 Packer at +/- 9636' Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Uod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joint (1) HES "X" (3.813" ID) 4-1/2" tubing joint (1) S3 Packer (c/w handling pups) 4-1/2" tubing joint (1) HES "XN" (3.725" ID) 32' 1825' 4227' 6815' 9550' 9595' 9636' 9689' 9700' Well TD at 12865' MD / 7170' TVD 4-1/2" 10' pup joint WEG (+/- 63 deg) Top Alpine at 9903' MD / 7106' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 10054' MD / 7128' TVD @ 87 deg 32' 1700' 3400' 5200' 6958' 6984' 7005' 7030' 7035' Colville River Field CD1-43 Production Well Completion Plan Formation Isolation Contingency Options Conductor to 114 1 " ' " , /2 Camco BAL-O SSSV N~pple (3.812 ID) WRDP-2 SSSV (2.25 ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line @1700'TVD=1825'MD @ 2813' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R~3 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Updated 07/06/00 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Uuleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 9400' MD (+500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear ~ 2000 psi JUL1 2 2000 ~ ~set 1 above the X joint landing nipple ~aska ~ &"~" ~ ~:'~Z~,, Baker S3 Packer set at +/- 9636 7" 26 ppf L-80 BTC Mod Production Casing ~ 10054' MD / 7128' TVD ~ 87 deg Well TD at 12865' MD / 7170' TVD ® N© CD1-43 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) aDrrVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2813 / 2400 14.2 1086 1532 7" 10054 / 7128 16.0 3225 2526 N/A 12865 / 7170 16.0 3243 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0,1 x 2400') - 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) - 0.1] x 2400: 1532 psi OR ASP: FPP - (0.1 x D) = 3225 - (0,1 x 7128') - 2512 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3243 - (0.1 x 7170') = 2526 psi Alpine CD1-43 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 -3500 PR -4500 -5500 -6500 -7500 \ I'~ I I I ~ ~ ........ /I I I =, /I II I I I ' II I I I I 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT JUL 12 ~r~¢n 9 5/8" Surface Casing run to 2813 MD/2400' TVD. Cement from 2813' MD to 2313' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2313' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2313'-1639') X 0.3132 ft3/ft X 1.5 (50% excess) = 316.6 ft3 below permafrost 1639' X 0.3132 ft3/ft X 4 (300% excess) = 2053.3 ft3 above permafrost Total volume = 316.6 + 2053.3 = 2369.9 ft3 => 534 Sx @ 4.44 ft%k System: Tail slurry: 534 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft%k System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 10054 MD ! 7128' TVD Cement from 10054' MD to +/- 9400' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (10054' - 9400') X 0.1268 ft3/ft X 1.4 (40% excess) = 116.1 ft3 annular volume 80' X 0,2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 116.1 + 17,2 = 133.3 ft3 => 116 Sx @ 1.15 ft3/sk System: 116 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk 1 By Weight Of mix Water, all other additives are BWOCement .................................... ~ ............................ iCreeted by bm~choel For: B Robertsonl Dote plotted: 6-Jul-2000 Plot Reference is CD1-43 Version ~11. Coordinotes ore in feet reference slot i~43. iTme Verticol Depths ore reference Estimoted RKBJ PHILLIPS Alaska, Inc.i Structure: CD#1 Well : 43 Field : Alpine Field Locofion : North Slope, Aloskoi 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 52O0 5600 6000 6400 6800 720O I RKB Elevation: 56' KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 ~ Beg ,3/100 Bid 234;94 AZIMUTH % 15.0018 O0 6290 (TO TARGET) ,,:. ~West Sak ~ /~.uu ............ ***Plane of Proposal*** ~ 24.00 UL~: O.UU aeg per ~, 27.00 % 30.00 33.00 Permofrost ~ 39.00 ~ Begin Turn ~, c4o ~%,,~ 9 5/8 Csg Pt. C30 MAXIMUM ANGLE 49.83 DEG K-2 Begin Bid/Tm ~ 45.94 .......... x,~ 48.2% dUL i22000. _ Albian-96 HRZ Beg Bid/Tm to gt DLS' 11 O0 deg per 100 ft 57 87 Miluveach A Torget-EOC-Csg Pt. A~p~n i i i i i i i i i i i i i i i i I i i i i i i i i i ~ i i i i i i i i 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 Verficol Section (feet) -> Azimuth 234.94 with reference 0.00 N, 0.00 E from slot #45 ! i i i , i i OeeC) q~deQ ID3!F~eA en.~/-> I I t I n 0 P'--0 0 0 Cxl 0 0 0 0 0 0 ,-- co 0 0 0 ,-- 0 0 0 0 0 0 t,O 0 00, lj E > 0 xl" 0 0 t'O i'O 0 0 0 0 0 0 '~- r'O 0 0 0 LO 0 0 0 0 0 0 0,,1 0 r~ (..ol 0 I"~ '-.O 0'o r..O ,-- r..O 0 ,-- -~- 0-~t- 0 0 ~- r.O r-... ,-- r..O Ob,-- r.D 03 ~ ~ 0 ~! Ll~ o,I I'~ 0 LO I'"- O0 ,---~') xh P'-- O0 0 t",- 0 P-- ,-- r.D P'-,aO C~ 0 0 ,-- ,-- ,-- ,--i g · ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,-- '~- i'~ O~ ~ t'O r'O I'O r'O r'O n 0 0 0 0 0 0 0 0 0 0 0 0 0 C~ 0'~ 0'~ C~ C~ r'O r,D I.D I'~ aO C~ C~ 0'~ O~ O~i © PHILLIPS Alaska, Inc. CD%I 43 slot %43 Alpine Field North Slope, Alaska JUL 1 2 2000 o~ & Gas Cons. Commission SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-43 Version #11 Our ref : prop3922 License : Date printed : 5-Jul-2000 Date created : 23-Mar-2000 Last revised : 5-Jul-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 31.954,w150 55 39.412 Slot Grid coordinates are N 5975607.668, E 385702.973 Slot local coordinates are 522.89 S 2280.80 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath PMSS <0-10548'>,,19,CD#1 PMSS <2827 - l1956'>,,19A,CD#l PMSS <0-10897'>,,3,CD%1 PMSS <0-8350'>,,26PHl,CD%l PMSS <7755-11134'>,,26,CD%1 PGMS <0-10255'>,,WD2,CD%l PMSS <476 - 11190'>,,34,CD#1 PMSS <297 - 9882'>,,44PH1,CD%l PMSS <9081 - 12811'>,,44,CD#1 PMSS <5946 - 10289'>,,1,CD%1 PMSS <0-7331'>,,1PH1,CD%l PMSS <0-11300'>,,13,CD#1 PMSS <0-9236'>,,22,CD~1 PMSS <384 - 14477'>,,23,CD~1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <0-8168'>,,35,CD%1 PMSS <763 - 7440'>,,36PH2,CD#l PMSS <6600 - 10654'>,,36,CD~1 PMSS <472 - 1545'>,,36PH1,CD%l PMSS <562 - 12134'>,,37,CD~1 PMSS <0-10224'>,,39PH1,CD#l PMSS <9146 - 13289'>,,39,CD%1 PMSS <0-11608'>,,42,CD#1 PMSS <0-8844'>,,45PH1,CD#l PMSS <7950-11950'>,,45,CD%1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD%l PMSS <10016 - 11136'>,,32,CD~1 PMSS <0-11067'>,,32PH1,CD%l PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-11934'>,,9PH,CD#l PMSS <10894 - 15350'>,,9,CD%1 PMSS <654 - 10956'>,,38PBl,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-12055'>,,40,CD%1 PMSS <0-9357'>,,16PH1,CD%l PMSS <8393 - 12600'>,,16,CD#1 PMSS <9810 - 10796'>,,24,CD#1 PMSS <0-13308'>,,6PH,CD#l PMSS <12550 - ???'>,,6,CD#i Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance 6-Apr-2000 239.9 30-Apr-2000 4-Jan-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 il-May-2000 23-May-2000 23-May-2000 27-Jun-1999 29-Feb-2000 15-Ju1-1999 28-Jun-1999 3-May-2000 15-Mar-2000 16-Mar-2000 28-Jun-1999 4-Jan-2000 22-Dec-1999 4-Jan-2000 26-Aug-1999 4-Jan-2000 22-Sep-1999 23-Dec-1999 4-Jan-2000 16-Nov-1999 3-Apr-2000 26-Mar-2000 7-Jun-2000 4-Jan-2000 23-Jan-2000 23-Jan-2000 20-Jun-2000 20-Jun-2000 13-Feb-2000 14-Feb-2000 28-Jun-2000 4-Jan-2000 25-0ct-1999 14-Jun-2000 30-Jun-2000 2-Jul-2000 239.9 400.1 169.6 169.6 1352.3 90 2 9 8 9 8 419 9 419 9 300 1 209 8 200 2 180 3 159 3 78 8 66 8 66 8 66 8 60 1 40 2 40 2 9 4 19 6 19 6 20.0 20.0 110.3 110.3 379.4 379.4 340.3 340.3 50.3 50.3 28.6 270.4 270.4 189.8 370.6 370.6 M.D. 262.5 262.5 250.0 275.0 275.0 275.0 262.5 100.0 100.0 250.0 250.0 100.0 250.0 100.0 100.0 337.5 387.5 400.0 400.0 400.0 250.0 262 5 262 5 312 5 200 0 200 0 275 0 275 0 100 0 100 0 262 5 262 5 100 0 100 0 275 0 275.0 337.5 100.0 100.0 262.5 250.0 250.0 Diverging from M.D. 262.5 262.5 12700.0 12440.0 12440.0 275.0 10700.0 9225.0 12260.0 250.0 250.0 100.0 250.0 100.0 11040.0 12860.0 387 5 400 0 400 0 400 0 12865 0 12865 0 12865 0 12640 0 ~1~ 200 0 12800 0 275 0 275 0 100 0 100 0 262.5 262.5 10222.2 10222.2 12865.0 12865.0 12865.0 100.0 100.0 10460.0 10420.0 10420.0 PHILLIPS Alaska, Inc. CD#1 43 slot #43 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ REPORT Your ref : CD1-43 Version #11 Our ref : prop3922 License : Date printed : 5-Jul-2000 Date created : 23-Mar-2000 Last revised : 5-Jul-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 31.954,w150 55 39.412 Slot Grid coordinates are N 5975607.668, E 385702.973 Slot local coordinates are 522.89 S 2280.80 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated Object wellpath PMSS <0-10548'>,,19,CD#1 PMSS <2827 - l1956'>,,19A,CD#1 CD1-4 Version #10,,4,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-8350'>,,26PHI,CD#1 PMSS <7755-11134'>,,26,CD#1 PGMS <0-10255'>,,WD2,CD%l CD1-2 Version #6 CDI-15 Version #2 CD1-10 Version #3 CD1-20 Version #3 CD1-21 Version #3 CD1-29 Version #2 CDI-17 Version #8 CD1-31 Version #2 CD1-30 Version #4 CD1-33 Version #4 CD1-28 Version #5 ,2,CD#i ,15,CD#1 ,10,CD#i 20,CD#I ,21,CD#1 ,29,CD#1 ,17,CD#1 ,31,CD#1 ,30,CD#i ,33,CD#1 ,28,CD%1 PMSS <476 - 11190'> ,34,CD#1 CD1-18 Version #2 ,18,CD#1 PMSS <297 - 9882'>,,44PHi,CD#1 Closest approach with 3-D Last revised Distance 6-Apr-2000 )238.5 30-Apr-2000 10-May-2000 4-Jan-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 8-Aug-1999 5-Apr-2000 10-Aug-1999 10-Aug-1999 10-Aug-1999 13-Jan-2000 19-Apr-2000 il-Aug-1999 il-Aug-1999 il-Aug-1999 13-Jan-2000 il-May-2000 7-Jun-2000 23-May-2000 )238.5 )389.0 )398.8 )168.1 )168.1 1350.3 409.0 279.0 328.8 228.9 219.0 139.2 258.5 118.9 128.9 )98.9 )149.0 )88.0 )249.1 )9.1 by an asterisk, e.g. 487.4* Minimum Distance method M.D. 275 0 275 0 262 5 262 5 287 5 287 5 300 0 262 5 262 5 262 5 262 5 262 5 262 5 275 0 262 5 262 5 262 5 275 0 275 0 262.5 200.0 Diverging from M.D. 275.0 275.0 10480.0 12865.0 12865.0 12865.0 300.0 262.5 262.5 262.5 262.5 262.5 262.5 10460.0 262.5 262.5 12860.0 12865.0 12865.0 262.5 9281.3 PMSS <9081 - 12811'>,,44,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-7331'>,,1PH1,CD#l PMSS <0-11300'>,,13,CD#1 PMSS <0-9236'>,,22,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-11492'>,,27,CD#1 35 Version#6,,35,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-10224'>,,39PHI,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-8844'>,,45PHi,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PHI,CD#1 CD1-32 Version #6,,32,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-11934'>,,9PH,CD#1 PMSS <10894 - 15350'>,,9,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 40 Version#6,,40,CD#l PMSS <0-12055'>,,40,CD#1 PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD#1 CD1-24 Version #5,,24,CD#1 PMSS <9810 - 10796'>,,24,CD#1 CD1-6 Version #6,,6,CD#1 PM$S <0-13308'>,,6PH,CD#1 PM$S <12550 - ???'>,,6,CD#1 23-May-2000 27-Jun-1999 29-Feb-2000 15-Ju1-1999 28-Jun-1999 3-May-2000 15-Mar-2000 16-Mar-2000 6-Jun-2000 28-Jun-1999 4-Jan-2000 22-Dec-1999 4-Jan-2000 26-Aug-1999 4-Jan-2000 22-Sep-1999 23-Dec-1999 4-Jan-2000 16-Nov-1999 3-ADr-2000 26-Mar-2000 8-Jun-2000 4-Jan-2000 7-Jun-2000 23-Jan-2000 23-Jan-2000 20-Jun-2000 20-Jun-2000 13-Feb-2000 14-Feb-2000 22-May-2000 28-Jun-2000 4-Jan-2000 25-0ct-1999 29-Jun-2000 14-Jun-2000 30-Jun-2000 30-Jun-2000 2-Jul-2000 )9.1( )418.6( )418.6( )299.1 )208.4 )198.6 ) 178.5 ) 157.4 )4453.2 )76.7 )63.9 )63.9 )63.9 )58.2 )38.8 )38.8 )7.7 )18.4 )18.4( )18.0( )18.0( )4233.0( )109.2( )109 2( )378 0( ) 378 0 ) 339 3 ) 339 3 )48 3 )48 3 ) 1150.1 )26.8 )269.5 )269.5 )9272.0 ) 187.9 11458.3 )369.2( )369.2( 200.0 250.0 250.0 250.0 275.0 262.5 262.5 375.0 5380.0 400.0 425.0 425.0 425.0 262.5 275.0 275.0 337.5 400.0 400.0 287.5 287.5 9356.3 262.5 262.5 275.0 275.0 262.5 262.5 300.0 300.0 12865.0 375.0 200.0 200.0 2009.7 275.0 1400.0 262.5 262.5 11660.0 250.0 250.0 10354.3 275.0 11780.0 12300.0 12865.0 5380.0 10000.0 425.0 10006 0 10660 0 12865 0 12865 0 12860 0 12640 0 2360 0 12865.0 10270.9 287.5 9356.3 6521.2 6521.2 10354.3 10354.3 10540.0 10540.0 12865.0 12865.0 12865.0 12865.0 10387.4 10387 4 12865 0 10760 0 11060 0 10420 0 10420 0 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 06, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-43 Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is August 05, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-43 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. JUL 1 2 2000 A~aska 0i! & Ga~ Cons. Commission ~ch0.ra,§a If you have any questions or require further information, plea contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Rob'~so~n~''~4'/ Senior Drilling Engineer Attachments CC: CD1-43 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko- Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com JUL 12 2000 Alaska 0ii & G~,,s Cor~s. Commission WELL PERMIT CHECKLIST .,,, COMPANY /~, ~'/.//./..~ WELL NAME ~)//-~ PROGRAM: exp.. INIT CLASS FIELD & POOL / ~ ~'"~) ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE ~ 12. Permit fee attached ....................... Lease number appropriate ................... Unique well name and.number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells ........ '~ . Sufficient acreage available in ddlling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur Without operation shutdown ........... 29. Is presence of H2S gas probable ................. DATE dev ddl serv wellbore seg ~' c.~ UNIT# " GEOL AREA .... N - - ¥ '~ ann. disposal para req ON/OFF SHORE (~)~,~_ GEOLOGY 30. can be issued w/o hydrogen sulfide measures ..... ~ -- 31. Data presented on potential overpressure zones ....... "//j ./'Y N 32. Seismic analysis of shallow gas zones. .......... ...~/f-t Y N APER hATE/ 33. Seabed condition survey (if.off-shore) ....... . . .,,~¢~... Y N f'_,~ ."~' / C/'~)34. Conta~t name/phone for weekly progress reports [~oratory only] Y N ANNULAR DISPOSAL35..With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (~ N APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... to surface; v~''~ '=l,/Z~ (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a (~O N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ~ N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: I°z O Z -i I- > c:\msoffiCe\wordian\diana\checklist (rev. 02/17/00)