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208-064
STATE OF ALASKA `. ALOKA OIL AND GAS CONSERVATION CONOSION 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 r vv.- Alter Casing r Change Approved Pr gram r Rug for Redrill r Perforate New Pool r Repair WellRe-enter Susp Well r Other: Kai-0 (d 2.Operator Name: 4.Well Class Before Work: 5.Permit to Dri/illl Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 208-064 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20573-00 7.Property Designation(Lease Number): 8.Well Name and Number: CR.0 CD2-75 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 23539 feet Plugs(measured) None true vertical 7355 feet Junk(measured) None Effective Depth measured feet Packer(measured) 12734 true vertical feet (true vertical) 6455 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3318 10-3/4 3354 2390 INTERMEDIATE 15669 7-5/8 15702 7370 LINER 8340 4-1/2 21198 7355 OPEN HOLE 2341 6.125 23539 7366 Perforation depth: Measured depth: 13761-21155 .„„a True Vertical Depth: 6863-7366 ��, ESI OCT 2 1 2015 Tubing(size,grade,MD,and ND) 3.5, L-80, 12881 MD,6517 TVD AOG Packers&SSSV(type,MD,and ND) SSSV-K-Valve @ 2200 MD and 1878 TVD PACKER-BAKER PREMIER PACKER© 12734 MD and 6455 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 899 1016 151 1086 222 Subsequent to operation 812 1076 122 1251 371 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations P Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ 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: 315-619 Contact Garrett McKee ( ,265-6549 Email Garrett.L.McKee a()conocophillips.com Printed Name rrett McKeeTitle Production Engineer Signature ? °� ...:'."<:-.7 Phone:265-6549 Date i%TL /0/2.-i-//5--- Form o/2Z�/� RBDMS�ULl. 2 2 2015 Submit Original Only 10-404 Revised 5/2015g (off /s' • • CD2-75 Report of Well Operations lor"- COnOCO dips CD2-75 : 501032057300 : 10/15/2015 10/14/15 Perform passing State Witnessed Performance test of K-Valve 10/11/2015 DRIFT TBG TO SSSV @ 2200' RKB w/3.84" CENT AND LIB, CLEAN NO MARKS. BRUSH AND FLUSHED X PROFILE IN SSSV WITH FULL BORE BRUSH. SET K VALVE (SN: K323) WITH NO EQ SUB @ 2200' RKB. DSO TO PERFORM CLOSURE TEST AFTER 4 HOURS OF FLOW TO WARM UP WELL. COMPLETE 10/6/2015 PULLED GAUGE ASSY @ 2188' RKB. **GAUGES STARTED @ 17:25 ON 10-4-2015. STOPPED RECORDING ON 10-6-2015 @ 8:40 AM**. NO CHANGE IN FISH. COMPLETE. 10/4/2015 SET 3" GAUGE HANGER (19" SLIP STOP,16" FLOW SUB,41" GAUGE CARRIER w/DUAL SPG's/OAL= 76") @ 2188' RKB. GAUGES @ 2194" RKB. PROGRAMED FOR 1 SEC SAMPLES. BATTERIES CONNECTED @ 17:25 PM. COMPLETE. 10/3/2015 DETERMINED UNABLE TO PASS GAUGE CARRIER PAST FLAPPER. JOB SUSPENDED. WAITING FOR TOOLS f/ KRU. 10/1/2015 EXERCISED FLOW TUBE @ 2200' RKB WITH 3.2" BLB & CONTROL LINE. EXCELLENT FLOW TUBE MOVEMENT. ABLE TO CATCH FLAPPER WITH C/L DUMPED. THICK PARAFFIN ON BRUSH. **FAIL FUNCTION TEST**. ATTEMPT TO SET SLIP STOP CATCHER. UNABLE TO PASS THRU TRDP @ 2200' RKB. RAN LIB TO SAME. **APPEAR TO HAVE PICTURE OF BROKEN FLAPPER**. IN PROGRESS. 9/23/2015 BRUSH & FLUSHED SSSV @ 2200' RKB w/ FULL BORE BRUSH. RAN Z5 EXERCISE TOOL TO SAME. FLOW TUBE MOVEMENT ON SSSV APPEARS TO BE GETTING WORSE. UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/22/2015 PUMPED 40 BBLS HOT DIESEL THROUGH WASH TOOL IN SSSV @ 2200' RKB. UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/21/2015 BRUSH & FLUSHED SSSV @ 2200' RKB w/ FULL BORE BRUSH. GOOD FLOW TUBE MOVEMENT&ABLE TO CATCH FLAPPER BUT UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/20/2015 DRIFT TBG TO SSSV @ 2200' RKB w/2.83" G-RING. BRUSH & FLUSHED SSSV @ SAME w/ FULL BORE BRUSH. RAN WASH TOOL TO SSSV @ SAME. UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/16/2015 SSSV failed to close during SVS Performance test ID • ° w ���jj� � THE STATE Alaska Oil and Gas °i\ L s Conservation Commission 333 West Seventh Avenue - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3.572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Garrett McKee Q Production Engineer c a V ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD2-75 SCANNED ,;AN 2 0) .")0 Sundry Number: 315-619 Dear Mr. McKee: 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, I Cathy P oerster Chair DATED this/Z day of October, 2015 Encl. RBDMS nrT 12 2015 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMIAION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing fl Operations Shutdown r Suspend E Perforate r Other Stimulate r Alter Casing r Change Approved Program Plug for Redrill r Perforate New Pool 7 Repair Well IW"" Re-enter Susp Well r Other: Install K-Valve 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory t'•"` Development 208-064 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20573-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? /1)4 Will planned perforations require spacing exception? Yes 1 No r CRU CD2-75 , 9. Property Designation(Lease Number): ' 7 10.Field/Pool(s): 1, _3(6 00?S- 3.Volt) c601 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): 23539 ' 7355 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' SURFACE 3318 10 3/4 3354' INTERMEDIATE 15669 7 5/8 15702' V D LINER 8340 _ 41/2 21198' _ UT 0 2 2015 MS i�o/�(/+(dal) $ <A GCC Perforation Depth MD(ft): f Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): /2 7t - Z, Lrio 3.5 L-80 12881 Packers/and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER • MD=12734 TVD=6455 SAFETY VLV-CAMCO TRMAXX-5E SSSV MD=2200 TVD= 1877 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program F BOP Sketch I Exploratory Stratigraphic I Development ( . Service f 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/8/2015 OIL Fi. WINJ I— WDSPL r Suspended r- 16.Verbal Approval: Date: GAS r WAG fa GSTOR r SPLUG I— Commission Representative: GINJ 1— Op Shutdown r Abandoned F- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Garrett McKee @ 265-6549 Email: Garrett.L.McKee@conocophillipt Printed Name Garrett McKee J� Title: Production Engineer Signature = , , ' /0/0015 Phone:265-6549 Date 10/2/2015 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -36- (•k9 Plug Integrity E BOP Test r Mechanical Integrity Test f Location Clearance Other: per{rri �7L-a-tt L,i,'fv7tfSc-C/ e /6 --t-'re fr 5 f ctftrfr. 71-441-r'1'` rooclf�cfie�7 k- vetlyL per arvviavtCL -ft-.s.-/- Fre-4vth�� tv h= /%".1e"/�ar-4 ?'rd 1� /'‘,1 -Jo v rr5-1-/.�y C yt lz al eOZ Pad. Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0— 404 APPROVEDHPGMMSBY c Approved by: P a i YO lI�S21ON,rEERths fro thTe gift OTIa.. .val. �+}Date:((��(( to- 'z f5 Form 10-403 Revised 5/2015 It 11A �/ )�,y � BD�s.7dtta�h etAirm and plicate (ATL /a/12"15-- ,4 /o/d//LI-- • • Alpine Well CD2-75 (PTD 208-064) Proposed Operating Plan 1. Continue operating the well in normal production service without an operable SSSV for up to 7 days, no later than October 9th, 2015. 2. Once the production rate stabilizes, perform a flowing survey to capture pressure and temperature data for the K-valve design. 3. Set the closing pressure of the valve and install the valve. 4. Stabilize well with K-valve installed and perform witnessed closure test. 5. Incorporate the K-valve test frequency into the current SVS testing cycle at CD2 pad. • Loepp, Victoria T (DOA) From: McKee, Garrett L <Garrett.L.McKee@conocophillips.com> Sent: Friday, October 09, 2015 2:19 PM To: Loepp,Victoria T(DOA) Subject: RE:CRU CD2-75(PTD 208-064, Sundry 315-619) K Valve Installation Attachments: CD2-75_SSSV Variance 10_9_15.docx Victoria, Attached is the additional information regarding the use of an alternate subsurface safety valve. Please contact me if additional information is needed. Thank you, Garrett McKee/Anu Sood WNS Production Engineer ConocoPhillips Alaska, Inc. 0: 907.670.4934 C: 907.943.0103 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent:Wednesday,October 07,2015 2:58 PM To: McKee,Garrett L<Garrett.L.McKee@conocophillips.com> Subject: [EXTERNALICRU CD2-75(PTD 208-064,Sundry 315-619) K Valve Installation Garrett, Please refer to AOGCC Industry Guidance Bulletin No 10-004 for information required for installation of an alternate subsurface safety valve. Please submit the required data for approval of this installation after you have obtained the data.We will then process the sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppealaska.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.aov 1 • • Alpine Well CD2-75(PTD 208-064) Colville River Unit well CD2-75 has a fish in the tubing-retrievable subsurface safety valve (SSSV)that is preventing setting a wireline-retrievable surface controlled subsurface safety valve. A downhole pressure operated valve or"K- valve"should satisfy the requirements of Industry Guidance Bulletin No. 10-004 with the attached information. Well Status CRU well CD2-75(PTD 208-064)was originally completed in May, 2008 as a development well. On October 1St 2015, during an attempt to repair the tubing-retrievable valve, the flapper appeared to become disconnected from the body of the valve. This resulted in a fish in the well. A K-valve installation is currently planned upon approval from AOGCC. The well was flowed from October 3rd, 2015 to October 6th, 2015 to design the K-valve. Proposed Operating Plan 1. Continue operating the well in normal production service without an operable SSSV for up to 7 days, no later than October 9th, 2015. 2. Once the production rate stabilizes, perform a flowing survey to capture pressure and temperature data for the K-valve design. 3. Provide information to the AOGCC as per Industry Guidance Bulletin No. 10-004. 4. Set the closing pressure of the valve and install the valve. 5. Stabilize well with K-valve installed and perform witnessed closure test. 6. Incorporate the K-valve test frequency into the current SVS testing cycle at CD2 pad. . • K-valve Data The K-valve will be set in the 2.812"X nipple of the TRMAXX-5E at 2200' MD. Storm Choked K Safety Valves Storm Choke"K safety valves are ambient-type,wireline- — retrievable valves with the largest flow area of all direct- controlled safety valves on the market.They are ideally suited for high-volume,low-pressure wells.These valves aremaw normally closed and precharged with a set dome pressure. When the well flowing pressure drops below the predetermined dome-pressure charge due to a rupture in flowline or surface equipment,the dome pressure and main valve spring close the valve,shutting in the well below the ' earth's surface.This valve contains a detent mechanism to provide a positive snap-action closure at the predetermined disaster rate of the valve.Its bore is not restricted by a flow bean.The valve is designed to resist pressure surges.A metal- to-metal(MTM)poppet valve and seat comprise the valves primary closure mechanism. The K valve is ideal for protecting wells with declining bottomhole pressure.This valve closes in situations where a pressure decline would not activate a valve with a flow bean. • To reopen the valve,the operator must fully equalize pressure • either by applying pressure in the tubing from the surface or by an equalizing prong.The valve will reopen when the tubing pressure acting on the internal piston area overcomes the dome charge. - 11.111 Applications • Wells with declining bottomhole pressure • High-volume,low-pressure wells • • Wells with no provisions for surface-controlled valves Features • Poppet closure • Large ports with capacity for high-volume wells • Designed to resist pressure surges Benefits • Installed and retrieved under pressure by wirelines ilt ,� methods Storm Liw • Adaptable to any Halliburton lock mandrel `�soap 1.: • Can be located in any Halliburton landing nipple • Can also be located on large bore intervention packers • • Pressure/Temperature Gauge Data The plot below shows the temperature and pressure at the SSSV during flowing conditions both before and after being choked. The light blue line is the targeted closure pressure of 390 psig. CD2-75's last unchoked production test was 861 BOPD at 16%watercut, with 867 Mscfd of formation gas and 2MMScfd of lift gas. The downhole temperature and the targeted closing pressure of 390 psi at the SSSV were used in accordance with the Winkler and Eads method to calculate a test rack dome pressure of 296 psi. This pressure should allow for testing of the K-valve by opening the choke to the full open position, Tubing Pressure at Valve(gauge) which will drop the WHP by 20-25 psi and cause the valve to go Per(psia) 404 closed. Temperature(deg F)at Valve CRU well CD1-34 (PTD 200-043) has a similar SSSV and testing Base Pressure 387.270718 procedure. Base Temp(TV-60) 23 Corrected Pressure 386.224163 TCF 0.95505481 Pressure/Temperature Graph Volume Ratio for Valve Size= 500 Pb @ 60= 372.471374 Test Rack Pressure= 296 450 -p moi.' ,III,1 Ji I. 400 .-114 Y r O5c ti°d l II I 350 300 ,IFT? s I �P 250 4 �1� 2-1 fa kc �'asp cl F y I ✓1 cM 200 150 —DH Pressure —Flow Tubing Pressure 100 —Downhole Pressure to Close K-Valve —DH Temperature 50 —Choke Position 0 0914% 1 C.14' .1,010•1)510NoV`iNSA�0�4I�51'1ol '1,SNOSrs. .s05I1�11o1M�1,S10SI/S3:5ao�IS1.101$5�15,C Time(day) • i Well History since SSSV Fail to Hold on 9/16/15 ConocoPhillips Well History CD2-75 : 501032057300 : 10/9/2015 10/6/2015 PULLED GAUGE ASSY @ 2188' RKB. **GAUGES STARTED @ 17:25 ON 10-4-2015. STOPPED RECORDING ON 10-6-2015 @ 8:40 AM**. NO CHANGE IN FISH. COMPLETE. 10/4/2015 SET 3"GAUGE HANGER (19" SLIP STOP,16" FLOW SUB,41" GAUGE CARRIER w/ DUAL SPG's/ OAL = 76") @ 2188' RKB. GAUGES @ 2194" RKB. PROGRAMED FOR 1 SEC SAMPLES. BATTERIES CONNECTED @ 17:25 PM. COMPLETE. 10/3/2015 DETERMINED UNABLE TO PASS GAUGE CARRIER PAST FLAPPER. JOB SUSPENDED. WAITING FOR TOOLS f/KRU. 10/1/2015 EXERCISED FLOW TUBE @ 2200' RKB WITH 3.2" BLB &CONTROL LINE. EXCELLENT FLOW TUBE MOVEMENT. ABLE TO CATCH FLAPPER WITH C/L DUMPED. THICK PARAFFIN ON BRUSH. **FAIL FUNCTION TEST**. ATTEMPT TO SET SLIP STOP CATCHER. UNABLE TO PASS THRU TRDP @ 2200' RKB. RAN LIB TO SAME. **APPEAR TO HAVE PICTURE OF BROKEN FLAPPER**. IN PROGRESS. 9/23/2015 BRUSH & FLUSHED SSSV @ 2200' RKB w/ FULL BORE BRUSH. RAN Z5 EXERCISE TOOL TO SAME. FLOW TUBE MOVEMENT ON SSSV APPEARS TO BE GETTING WORSE. UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/22/2015 PUMPED 40 BBLS HOT DIESEL THROUGH WASH TOOL IN SSSV @ 2200' RKB. UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/21/2015 BRUSH & FLUSHED SSSV @ 2200' RKB w/FULL BORE BRUSH. GOOD FLOW TUBE MOVEMENT&ABLE TO CATCH FLAPPER BUT UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 9/20/2015 DRIFT TBG TO SSSV @ 2200' RKB w/2.83" G-RING. BRUSH & FLUSHED SSSV @ SAME w/ FULL BORE BRUSH. RAN WASH TOOL TO SSSV @ SAME. UNABLE TO ACHIEVE PASSING CLOSURE TEST. IN PROGRESS 3/22/2015 HOT FLUSHED TRDP W/40 BBLS CRUDE. BRUSHED & EXERCISED TRDP @ 2200' RKB UNTIL FUNCTIONING PROPERLY. DSO PERFORMED PASSING CLOSURE TEST. COMPLETE. 9/22/2014 DRIFT TBG TO SSSV @ 2200' RKB w/2.83" G-RING, BRUSHED SSSV @ SAME. PERFORMED GOOD CLOSURE TEST. COMPLETE Regards, Garrett McKee WNS Production Engineer ConocoPhillips Alaska, Inc. 0: 907.265.6549 C: 505.801.1187 Garrett.L.McKee(a�conocophillips.com - �, WNS CD2-75 C0n0C+D�1ilip5 -a Well Attributes Max Angle&MD TD • AIaSk,i,1110.. - Wellbore APWWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) icxKn,»+,mln 501032057300 ALPINE PROD 92.75 16,816.85 23,539.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP Last WO: 36.35 6/2/2008 Well Gorda,HORIZONTAL-CD2-75,7/30/201311 06.57 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ---- -- -Last Tag: Rev Reason:Show Surface CSG Patch osborl 7/30/2013 HANGER,31 .:,;,;411111 ,� Casing Strings CONDUCTOR, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...IString Top Thrd 36.114CONDUCTOR 16 15.250 36.0 114.0 114.0 65.00 H-40 Welded _mai,Y Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVO)...String Wt..String...String Top Thrd SAFETY VLV, 111, SURFACE 10 3/4 9.950 36.0 3,353.6 2,390.1 45.50 L-80 BTCM 2200 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd I INTERMEDIATE 7 5/8 6.875 33.3 15,702.0 7,370.3 29.70 L-80 BTCM SURFACE, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 36-3,354 GAS LIFT, OPEN HOLE 61/8 21,198.2 23,539.0 7,355.4 - 5,670 ■ Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth IND)...String Wt...String...String Top Thrd GAS LIFT, Il LINER 41/2 3.958 12,857.9 21,198.2 7,365.8 12.60 L-80 IBT 10,771 - Liner.Details GAS LIFT, mar Top Depth Y 12,676 FISH,12,700 (TVD) Top Teel Nomi... PACKER, - Top(MB) (ftKB) (") Item Description Comment ID(in) 12.734 NIPPLE,12,813 12,857.9 6,507.6 65.39 SLEEVE "HR"Liner Setting Sleeve 5.75'10 5.750 12,872.0 6,513.5 65.44 NIPPLE "RS"PACKOFF SEAL Nipple(4.89"ID) 4.890 :;;I 12,875.9 6,515.1 65.45 HANGER Baker FLEX-LOCK Liner Hanger 4.880 12,885.7 6,519.1 65.49 XO BUSHING CROSSOVER BUSHING 5.5x4.5" 3.940 WLEG,12,881 " Tubing Strings IN Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 4,5x3.5" 3 1/2 2.992 30.7 12,882.1 6,517.7 9.30 L-80 EUEMOD 73,761-7 PERFP,3.765 IIECompletion Details Top Depth PERFP, ® (ND) Top Incl Nomi... 13,938-13.943 :11111 Top(ftKB) (ftKB) (°) Mem Description Comment ID(in) PERFP. � 30.7 30.7 -0.02 HANGER FMC 4.5"TUBING HANGER 4.500 14,155-14.160 _ 128.4 128.4 0.30 XO-Reducing 4,5"OD,ID 3.958",12.68,L-80 x 3.5" 3.500 PERFP, � = 2,200.0 1,877.4 58.94 SAFETY VLV CAMCO TRMAXX-5E SSSV 2.812 14,377-14.382 PERFP, 12,733.9 6,455.4 64.76 PACKER BAKER PREMIER PACKER 2.980 14,599-14,603 12,813.3 6,488.9 65.25 NIPPLE HES'XN'NIPPLE w/2.75"NO GO PROFILE 2.720 PERFP, t 14,816-14,821 11. 11111 I. 12,881.1 6,517.2 65.47 WLEG Wire Line Entry Guide 2.970 15,034-19039 -,.IE g Other.In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.).... Top Depth PERFP, a (TVD) Top incl 15,255-15.261 Top(EKE) (ftKB) (°I Description Comment Run Date ID(In) PERFP, ` 12,700.0 6,440.8 64.59 FISH 1"HES SPG 11/8/2008 0.000 15,477-15.49z . PATCH SURFACE CASING PATCH:16'x 12.75".500 x65 SC 7/14/2013 10.7... SLEEVE;BEGINNING AT BOTTOM OF STARTER HEAD DOWN 16'7" PERFP, 15597-15702\ NTERMEDIATE, ill - ■ Perforations&Slots 33-15.702 Shot PERFP, ft Top(TVD) Btm(TVD) Dena 15,912-15.917 Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment PERFP, H. 13,761.0 13,765.0 6,863.4 6,864.9 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP 16,126.16.133 --an 13,938.0 13,943.0 6,926.1 6,927.8 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP PERFP, _ 14,155.0 14,160.0 6,999.0 7,000.6 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP 16,34516,350 PERFP, If 14,377.0 14,382.0 7,069.8 7,071.3 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 12"HOLES/PUP 16,567-16.572 -ML 14,599.0 14,603.0 7,135.4 7,136.5 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP PERFP. __tg 14,816.0 14,821.0 7,194.1 7,195.4 ALPA,CD2-75 5/302008 6.0 PERFP SIX 1/2"HOLES/PUP 16,780-16.785 Ili 15,034.0 15,039.0 7,247.1 7,248.3 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP PERFP, • 1859517,090 -MR 15,255.0 15,261.0 7,295.1 7,296.3 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP PERFP, _V 15,477.0 15,492.0 7,335.0 7,337.5 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP 17,21417,215 15,697.0 15,702.0 7,369.8 7,370.3 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP PERFP, 11161 17.430-17.435 - WNS • CD2-75 ConocoPhillips 01 Alaska,hl. ComoOetellips KB-Grd(R) Rig Release Date "' 36.35 6/2/2008 Well Confyl:HORIZONTAL-C132-75,7/30/201311:06:57 AM schematic-Actual & Perforations Slots - Shot CONDUCTOR, 36-114 Top(TVD) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date (sh-. Type Comment SAFETY VLV, it 20,711.3 20,716.1 7,369.3 7,369.2 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP 2,200 20,928.6 20,933.4 7,365.1 7,365.2 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP SURFACE, — — 21,150.3 21,155.1 7,366.4 7,366.3 ALPA,CD2-75 5/30/2008 6.0 PERFP SIX 1/2"HOLES/PUP 36-3,354 GAS LIFT, Stimulations&Treatments 5.670 .___.__- Bottom GAS LIFT, Min Top Max Btm Top Depth Depth 10,771 Depth Depth (ND) (ND) GAS LIFT, F ane (RKB) (RKB) (RKB) (RKB) Type Date Comment 12,676 FISH,12,700las 15,912.0 21,155.0 7,391.8 7,366.3 FRAC 3/17/2011 Alpine'A'formation FRAC;pumped 756,171#of PACKER. 16/30 Colorado Whitesand,754,989 behind pipe; 12,734 107%of design. NIPPLE,12.813 Notes:General&Safety End Date Annotation IF4/20/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 WLEG,12,881 A. .. 1 — - „ w MI FP, - EN 13,761P-1E3,R765 PERFP, 13,938-13,943PERFP, PERFP, M 14,155-14,160 0 FP, til. 14,377-14,PER382 IIIM PERFP, ME M 14,599-14,603 ERFP, PERFP, 14,816-14,821 _ PERFP, 116 15,034-15,039 PERFP, 15,255-15,261 15,477-1 --- PERFP, .5,492 PERFP, ir . 15,697-15,702 NTERME15,702 3315,702 E , 1' 15,912-P15,9RF1P7 i 16,128PE-ERFPRFP, PERFP, 16,345-16,350 i PERFP, I 16,567-16,572 - Mill PERFP, 1 16,780-16.785 i 16,995PrP, p MIL 00 - ; :41.- PERFP,5 17,21417,21 11111 PERFP, 17,430-17,435 5 PERFP, 17,651-17,656 an ERFP, PERFP, - 17,872 RFP7 P, PERF 18,091-18.096 PERFP, PERFP, 18304-18,309 PERFP, 18 15,52 FRAC, FRAC,15,9112 $ PERFP, -- --- 18,743-18,748 PERFP, I. ■ B pa 18,962-18,967 — RFP, — • • 19,184PE19,185 - ■ ■ PERFP, 19,402-19,406 - PERFP. 1-E-f- 19,622-19,626 PERFP, 19.842-19,847 - PERFP, - - 20.060.20,065 PERFP, • •' 20,27620,281 III PERFP, • • 20,49 PERF 5 I PERFP, I. 20,711-20,716 PERFP, 20,929-20,9333 lilli PERFP, 21,15421,155\ )ir LINER. \ 12,858-21,198 OPEN HOLE, Mil 21,198-2 2 TD, 33,5,53399 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q ~ - Q ~Q (~. Well History File Identifier nizin done Two-sided (I (II II II II II I V III ^ Rescan Needed II (II II II ~I I I II I III Orga g c RES AN DIG AL DATA Color Items: Diskettes, No. , ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria Date: , Project Proofing BY: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: l ~ l~ ~ lsl Date: ~ / / O Scanning Preparation J x 30 = BY: _ Maria Date:. Production Scanning Isl ~~ + =TOTAL PAGES ~~ (Count does not include cover sheet) Isl Stage 1 Page Count from Scanned File: ~_ (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ' O / D ~s~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. III II II II I II II I I II ReScanned III IIIIIIIIIII VIII BY: Maria Date: ~s~ his file: Quality Checked III IIIIII III IIII III Comments about t P 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMOtION REPORT OF SUNDRY WELL OPERATIONS . 1.Operations Performed: Abandon r Repair w ell [7 Rug Perforations r Perforate r Other SC repair Alter Casing r Rill Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown 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 F7• Exploratory r 208-064 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service (® 50-103-20573-00• 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380075, ADL0387207 CD2-75 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Colville River Field/Alpine Oil Pool • RECEIVED 11.Present Well Condition Summary: JUL 2 3 2013 Total Depth measured 23539 • feet Plugs(measured) none true vertical 7355 feet Junk(measured) 12700' L•� Effective Depth measured 21198 feet Packer(measured) 12734 true vertical 7365 feet (true vertical) 6455 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 0 0 SURFACE 3318 10.75 3354 2390 0 0 INTERMEDIATE 15669 11 15702 7370 0 0 LINER PERF PUP 8340 6.5 21198 7366 0 0 OPEN HOLE 2341 6.181 23539 7365' 0 0 Sleeve 16'7" 12.75#x65.500 wall 0 0 0 Perforation depth: Measured depth: Slots frm 13761-21155, �/��� True Vertical Depth: Slots frm 6863-7366, SCANNED NOV 0 8 2013 Tubing(size,grade,MD,and TVD) 3.5, L-80, 12881 MD, 6517 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 12734 MD and 6455 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured):N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A NA N/A N/A Subsequent to operation N/A N/A NA N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development . Service r Stratigraphic r 16.Well Status after work: Oil t , Gas r WDSPL r Daily Report of Well Operations X GSTOR r VVINJ 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: 313-342 Contact KelD/Lyons/Brent ,tgat s Email n1617Ccr�ConocoPhillips.com Printed Name ly L ons Title Problem Well Supervisor _ Signature Phone:659-7224 Date 7/21/13. '- __.. vi- F RBDMS JUL 2 4 20`.: 813 )1)3 Form 10-404 Revised 10/2012 ��., Submit Original Only • • RECEIVEb ✓ JUL 2 3 2013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 21, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well CD2-75, PTD 208-064, Sundry 313-342 surface casing repair. Please call Kelly Lyons or Brent Rogers at 659-7224 if you have any questions. Sincere g( Kelly s ConocoPhillips Problem Wells Supervisor • CD2-75 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/25/131SET 2.81"XXN PLUG @ 12,813' RKB IN TBG. 07/06/131 removed 14'8" of 16"conductor. Leak discovered at 12 o'clock on the SC 07/10113ISent e-mail to AOGCC for opportunity to inspect SC damage before welding sleeve. 07/13/131 Proceeded to do the first of three passes on the 16' 7"X 12.75 .500 x65 SC sleeve. 07/14/131 Finished welding the final two passes on the SC sleeve. Awaiting Kakivik's MT&UT results. 07/15/13 Sent e-mail to AOGCC for opportunity to inspect surface casing repair(waved by Robert Noble). 07/15/13 MT& UT results passed. Rigged up equipment to perform MIT-OA. Pressured up OA to 1800 PSI fora 1 hour monitor. Initial T/I/O= Si0/0/1800, 15 min= Si0/0/1770, 30 min= Si0/0/1740. Pressured back up to 1800 PSI. 15 min= Si0/0/1000. Attempted to repressure up to 1800 PSI with no gain due to the fact of an open shoe, 30 min= 1000. Final= 1000. Bled OA back to 0 PSI. Insulators denso wrapped conductor. Flew in and tac'd into place the 20'4"X 16" H40 65# conductor and then proceeded to weld into place. 07/17/13 Welded metal cellar box onto wellhead conductor. Excavation ready to be backfilled to pad grade. � I I I * „� ' ®ConocoPhillips • • • - Alaska, Inc . • . -- This photo is NNW.r •, copyright by IN) ConocoPhillips Alaska, Inc. ;• � ' and cannot be .r _° - released or N t*'; published without • express i ..r ., .' ' : ..:.......,-, , .- :".. -'3 W. . . ..... „......_,:, ,,„ ' . . . • .. . . _ , , . , ...., . , __. .. • -,. . • . - - =w a. ir . . . _.27_,,,_„, # hos_ . .77_1,, # . ,.....r.. . !... __ . : . . . , .• k� s • ''•, . . ,,. . • • . r t 4 • - 9 . . ♦ • I iiii . • • • 0 it 0 .....„.,.......--- ......_ _,.....------- --------------7, ' -- , " '- . ' , e 111 • • '. f.,4"..::‘,"';.',-...::!'.:-..-7...--t'''1-;'''''''..''''''-it:::''.:::::7-'''''4i iiiii ' ."...!,', r; '.1.-'''.`'''''' ' ..., _ '-I . . • ,- f - , . ,... 4.4A4 ii. 4.43,, ._ . — . . .. . . . .,,t,,,,,',..t.'' ';.,:,-4.,,..ii4 ., •44, , ,,,,,,,..e„,,, : ,.. ...,..„-,:. :-... .• ... . . '4* Z•14%,41t ...4 . 4. -'•• ,, ,,, *40 '-* z...,:-.4.: t ..,_ : ..,,,- ,',‘• •t„..,14`4.:' ' -' * '''46,-i-,-*".,::-..*-"- ` ir -'-i-gb!'. . '' ,-iti':':;,.-*--*''...1.4• 4,,-,''.-- ' . •;,1',.---,-, - .''--..1"774-,I-. ' ,:. 1.' ",,..-.,... i'`ii::. ,-,-, '''' 'ikit '44011$'1*-'' ''' ' '''''• ' '' 'If ' ' • • • • .L. * • ' .1,it,'''.--s• . IP I , ,. , • 410111111k ' .., • , . •1 ' *Or . , . . . - , ... - 4ter . . 4,,t,,,,,,* i ,14...., , 4.. ' t ■',, ' .4"' ',,' , 4 Aga t - 14/444' 4.- - , • . ' 4 4, * ' ...,,,,, ' 4 ' * * 4 • • • • . 4.. • e • • ..4:4i'4°,*',44 % 44,4;;,,.4*t -4-• 4 1 e ,of ,..-# t ir.k„, i ',. . I , . ” i iff*•• 5 cp cn --Z5' 0 cn ze 4 ... * ' i /0 # / ,.. , . is , ' . ./. # .-- ' -,, ; #,., . - sir 1 i ,.. — .„ , Aik , ;!, -Pt'- . ./ .4 (--- . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate p- Other Alter Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved F ogram J Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ — 208 - 064 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 50 1 - 20573 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075, 387207, ASRCNPRA02 - CD2 -75 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 23539 feet Plugs (measured) None true vertical 7355 feet Junk (measured) 12700' Effective Depth measured 21198 feet Packer (measured) 12734 true vertical 7365 feet (true vertucal) 6455 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3318 10.75 3354 2390 PRODUCTION 15669 7 -5/8" 15702 7370 LINER 8340' 4.5" 21202' 7366' RECEIVED 1- , i 11 `1n`i`, Perforation depth: Measured depth: perfd liner 13761' 21155' True Vertical Depth: 6863'-7366' Alaska thl & En Cons Commission' Tubing (size, grade, MD, and TVD) 3.5, L -80, 12881 MD, 6517 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 12734 MD and 6455 TVD SAFETY VLV - CAMCO TRMAXX -53 SSSV @ 2200 MD and 1877 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 15912'- 21155' Treatment descriptions including volumes used and final pressure: 756171# of 16/30 Colorado whitesand 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1524 3020 9 -- 258 Subsequent to operation 2011 3807 98 -- 262 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 — Service r Stratigraphic 15. Well Status after work: , Oil ✓ Gas r WDSPL Daily Report of Well Operations XXX GSTOR E WINJ ; WAG r GINJ r SUSP r 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: 309 -015 Contact Tim Schneider @ 265 -6859 Printed Name Tim Schneid Title WNS Staff Production Engineer Signature , Phone: 265 -6859 Date 3 / . // RBDMS APR 14 go c '. /Y• "( Form 10-404 Revised 10/2010 u it Original Only WNS CD2 -75 Cons Phillips - Well Attributes Max Angle & MD TD AlBS`k& Inc. ' - Wellbore APIIUWI (Field Name Well Status Inc!() 1MD (ftKB) Act Btm (ftKB) LctaYhitkgs' s 501032057300 ALPINE PROD 92.75 I 16,816.85 23,539.0 " Comment I H2S (ppm) Date A nnotation End Date KB (ft) Rig Release Date n ai( contig HoRI� i -74 ,3ngr74 119 . A SSSV: TRDP _ rife .Last WO: _ _ 36.35 6/2/2008 � _ &++wg -Aa I AM � notation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag :_ _ Rev Reason FRAC SLEEVE f Imosbor 3/18/2011 -- Casing Strings 'E Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd CONDU __ CONDUCTOR 16 15.250 36.0 114.0 114.0 65.00 H -40 Welded Casing D 3 6 -114 . -� Description String 0... String ID ... Top (ftKB) Set Depth (f... Set et Depth (ND) ... String Wt... String ... String Top Thrd SLEEVE, 2,200 .4. SURFACE 103/4 9.950 36.0 3,353.6 2,390.1 45.50 L - 80 BTCM SAFETY VLV, _ - - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (1VD) ... String Wt... String -- String Top Thrd 2,200 INTERMEDIATE 7 5/8 6 875 33.3 15 702.0 7,370.3 29.70 L BTCM i. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) String Wt... String ... String Top Thrd SURFACE LINER PERF PUPS 41/2 3.958 12,857 9 21,198.2 7,365.8 12.60 L - 80 IBT 36 -3 GAS LIFT, _ -- 3.ti�Er ' `. Liner Details 5,670 1 Top Depth (ND) Top Inc' Nomi... GAS LIFT, I Top (ftKB) (R (') Item Desviption Comment ID (in) 10,771 - - 12,857.9 6,507.6 65.39 SLEEVE "HR" Liner Setting Sleeve 5.75" ID 5.750 12,676 - -- FISH, 12,700 - - - 12,872.0 6,513.5 65.44 NIPPLE "RS" PACKOFF SEAL Nipple (4.89" ID) 4.890 PACKER, I ' 12,875.9 6,515.1 65.45 HANGER Baker FLEX- LOCK Liner Hanger 4.880 12,734 _ NIPPLE, 12,813 - - - - -- d 12,885.7 6,519.1 65.49 X0 X0 -51/2' BTC X41/2 "IB( - 3.940 Tubing Strings d Tubing Description String 0.. Sir n ID .. Top (ftKB) Set Depth f... Set Depth (ND -. String Wt.. IStrin String Top Thrd -"5- 9 P 9 P1 P( 1 9 9��� 9 . _ l UBING 3 1/2 2 992 I 30. / 12 882 -1 6517 7 1 9.30 L -80 EUEMOD i WLEG, 12,881 t " Com letion Details „ ,. - -_ - -� Top Depth (7110) Top Incl _ Mani... Top MKS) (ftKB) (7 gem Description Comment ID (in) f 30.7 30.7 -0.02 HANGER FMC 4 -5" TUBING HANGER 4.500 -- - ' 128.4 128.4 0.30 X0 - Reducing 4.5" x 3.5" 3.500 3 2,200.0 1,877.4 58.94 SAFETY VLV CAMCO TRMAXX -53 SSSV 2.812 1 1 12,733.9 6,455.4 64.76 PACKER BAKER PREMIER PACKER 2.980 1 1 12,813.3 6,488.9 65.25 NIPPLE HES'XN' NIPPLE w/2.75" NO GO PROFILE 2.720 1 1 12,881.1 6,517.2 65.47 WLEG Wire Line Entry Guide 2.970 1 1 j Other In Hole [reline retrievable plugs, valves, pumps, fish, etc.) I Top Depth (ND) Top Inc' Top (8806) (ftKB) (1 Description Comment 2.81" FRAC SLEEVE (DA Run Date ID (in) 2,200.0 1,877.4 58.94 SLEEVE L -56 ") 3/14/2011 2.310 NTERMEDIATE, 12,700.0 6440.8 6459 FISH ' HES SPG 11/8/2008 0.000 33-15,702 i Perforations & Slots PERFP, - 15,912- 15,917 Top (7110) Btm (TVD) Dens PERFP. - ".�. Top B�fWKB _ (8KB) OMB) Zone Date ( Type Comment _.. 16,128 - 16,133 - I 15,912.3 15,917.0 7,391.9 7,392.5 ALPB, CD2 -75 5/3W2008 6.0 PERFP SIX 1/2" HOLES /PUP PERFP, _ 111 16,128.5 16,133.2 7,408.3 7,408.7 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 16,345 - 16,350 - 1 F 16,345.2 16,350.5 7,419.8 7,419.9 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP. 16,567.1 16,571.9 7,415.9 7,415.7 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 16,567 16,572 16,780.0 16,784.7 7,408.5 7,408.3 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP' I i 16,994.8 16,999.6 7,404.0 7,404.0 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 16,780 ' ''. . PERFP, 17,209.8 17,214.6 7,402.5 7,402.8 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/T HOLES/PUP 16,995 1 17,430.0 17,434.8 7,405.0 7,404.9 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP, "._ 17,651.2 17,655.9 7,399.3 7,399.1 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 17,210 - 17,215 17,872.1 17,876.8 7,398.7 7,398.7 ALPA, CD2 - 75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 17,430 - 17 PERFP ,435 18 18,095.8 7,398.4 7,398.4 ALPA, CD2 - 75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 18,303.7 18,308.5 7,397.0 7,397.0 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2' HOLES/PUP ERFP,_ 17,651 - P 17,656 18,524.6 18,529.4 7,393.9 7,393.8 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2' HOLES/PUP PERFP, 18,743.1 18,747.8 7,387.1 7,387.0 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 17,872 17,877 18,962.2 18,967.0 7,385.9 7,385.9 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES /PUP PERFP, 19,180.4 19,185.2 7,383.2 7,383.2 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2' HOLES/PUP 18,091 18,096 - ..._. r , 19,401.6 19,406.4 7,384.9 7,384.8 ALPA, CD2 - 75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP, 18,304 19,621.6 19,626.4 7,380.1 7,379.9 ALPA, CD2 - 75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP, 18,525 - 16,529 1 9,842.0 19,846.8 7,376.1 7,376.0 ALPA, CD2 - 75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP " y FRAC, 15,912 7 20,060.3 20,065.1 7,375.2 7,375.2 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP, „ 4 20,276.0 20,280.7 7,373.6 7,373.6 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES /PUP 18,743 - 18,748 20,489.9 20,494.7 7,371.4 7,371.4 ALPA, CD2 - 75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP PERFP._ I 18,962 - 18,967 - 20,711.3 20,716.1 7,369.3 7,369.2 ALPA, CD2 -75 5/30/2008 - 6.0 PERFP SIX 1/2" HOLES/PUP PERFP, ;4 y„r. 20,928.6 20,933.4 7,365.1 7,365.2 ALPA, CD2 -75 5/30/2008 6.0 PERFP SIX 1/2" HOLES/PUP 19.160.18.185 '�°" 2'1,150 _ _ - -- .3 21,155.1 7,366.4 7,366 -3 ALPA, CD2-75 5/30/2008 6 0 PERFP SIX 1/2" HOLES /PUP 19,029,406 Stimulations & Treatments Bottom - - - -- - PERFP, Min Top Max Btm Top Depth Depth 19,622 - 19,626 Depth Depth (ND) (7110) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment PERFP, 15,912.0 21,155.0 7,391.8 7,366.3 FRAC 3/17/2011 Alpine'A' formation FRAC pumped 756,1718 of 19,642 •4 -�- 16/30 l:oloratlo Whltesand, 754,989 behintl pipe; PERFP, ___ ,, r 107% of design 20,060- 20,065 { ____.. ___.? -- L... _ -- �.. . Notes: General & Safety PERFP,_ - __ --- End Date _ - Annotation - -- -- zo,vs- 20,261 4/20/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PERFP, - - _- 20.490- 20.495 PEF,_ - y r 7 Y ;-. ,.,:as; ° =_ 20.711 - 20.R71P8 andrel Details - - - '_ Top Depth Top � 2- - g PoA PERFP, (TVO) Intl OD Valve Latch Se TRO Run 20,929- 20,933 Stn Top (ftKB) (ftKB) (°) MaO, Mod.1 (in) San TYpe TYpe (in) (pel) Ron Dab Co..,.. PERFP, 1 5,670 4 3,397.5 66.71 CAMCO KBMG GAS LIFT DMY BK 0.000 0.0 3/13/2011 21,150-21,155 ., , _ i LINER PERF s 2 10 5 5 64 CAMCO KBMG GAS LIFT DMY BK 0.000 0.0 3/13/2011 PUPS. I TD, 23,539 23,539 12. 3 12,675.7 6,430.4 64.46 CAMCO KBMG GAS LIFT GAUGE BK 0.000 0.0 3/12/2011 TD, - CD2 -75 Well Work Summary DATE SUMMARY • 3/3/41 BRUSH AND FLUSHED SSSV @ 2200' RKB. PERFORMED CLOSURE TEST. PASSED. COMPLETE. 3/12/11 GAUGED TBG TO 2.79" TO XN -NIP @ 12,813' RKB. SET CAT SV @ SAME. PULLED OV @ 12,675' RKB & GLV @ 10,771' RKB. IN PROGRESS. 3/13/11 PULLED GLV @ 5670' RKB. SET DVs @ 5670' & 10,771' RKB. FLUID PACKED TBG & IA WITH 391 BBLS SEAWATER & 150 DEAD CRUDE. SET 1" HES SIDE POCKET GAUGE @ 12,675' RKB. LRS TO MIT IA & TBG. IN PROGRESS. 3/14/11 PULLED CAT SV @ 12.813' RKB. SET 2.81" FRAC SLEEVE @ 2200' SLM. READY FOR SLB FRAC CREW. 3/17/ 1 ALPINE "A" FORMATION FRAC. PUMPED A TOTAL •F • - s nF 16 Q c of ()RAM WHITESAND WITH 754,989 PLACED BEHIND PIPE. FRAC PUMPED TO 107% DESIGN. FLUSH JOB TO COMPLETION, WITH 102 BBLS XL GEL, 82 BBL LINEAR GEL AND 55 BBLS DIESEL FREEZE PROTECTION. 3/23/11 TBG OPEN TO 2.85" TO 2200' RKB. PULLED ISO SLEEVE @ 2200' RKB. GAUGED & BRUSHED TBG TO 12813' RKB; RECOVERED 3" PIECE RUBBER. SET 2.81 SV @ 12813' RKB. PULLED SPG @ 12675' RKB; GAUGE MISSING 3 -3/8" x 1" NOSE CONE. BRUSHED & GAUGED TBG TO 12813' RKB. SET 1/4" OV @ 12675' RKB. IN PROGRESS. 3/24/11 BRUSHED & GAUGED TBG TO 12813' RKB. PULLED DV @ 10771' RKB, SET GLV @ SAME. PULLED 2.81 SV @ 12813' RKB; RECOVERED NOSE CONE IN SV. SET 2.81" x 2.31" ISO SLEEVE @ 2200' RKB. COMPLETE. 4/2/11 PULLED 2.81" FRAC SLEEVE @ 2200' RKB. COMPLETE. 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 05, 2011 2:37 PM To: 'Schneider, Tim S.' Subject: RE: CD2 -75 Sundry: 309015 Extension (PTD 208 -064) Tim, As long as there is no scope change to the sundry procedure an extension will be granted until March 31, 2011. Regards, Guy Schwartz Senior Petroleum Engineer 4tatiki 0 'I all AOGCC 793 -1226 (office) 444 -3433 (cell) Original Message From: Schneider, Tim S. [mailto:Tim.S.Schneider @conocophillips.com] Sent: Wednesday, January 05, 2011 2:10 PM To: Schwartz, Guy L (DOA) Cc: Allsup- Drake, Sharon K Subject: CD2 -75 Sundry: 309015 Extension Guy, Happy New Year! We would like a 2 month extension on a Sundry (309 -015) approved on January 21, 2009 that will expire on January 21, 2011 to stimulate CD2 -75 - Alpine producer. CPAI was unable to execute the frac during the 2009 and 2010 ice road seasons. I've attached the approved sundry along with a wellbore schematic. Regards, Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine * Phone: 907 - 265 -6859 * Fax: 907 - 265 -1515 * Mobile: 907 - 632 -8136 * Email: tim .s.schneider @conocophillips.com 1 DATA SUBMITTAL COMPLIANCE REPORT 2/9/2010 Permit to Drill 2080640 Well Name/No. COLVILLE RIV UNIT CD2-75 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20573-00-00 MD 23539 TVD 7355 Completion Date 6/1/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments pt LIS Verification 3326 23539 Open 7/16/2008 LIS Veri, GR, RPD, FET, / ~ f ~ ~ i i it "I d i /R i [ O en 7/16/2008 RPS, RPM, RPX, ROP Gra hics EMF CGM PDF D C Pd v 16617 n uct on es st y ~ ~~ q p p , , in MD and TVD for EWR ' logs. t,ED C Pdf 16616NInduction/Resistivity jt~.( ~c326 23539 Open 7/16/2008 Graphics GR, RPD, FET, RPS, RPM, RPX, ROP LL/og Induction/Resistivity 25 Col 114 23539 Open 7/16/2008 MD ROP, DGR, EWR og/~ ' Induction/Resistivity 25 Col 114 23539 Open 7/16/2008 TVD ROP, DGR, EWR ~1 D Asc Directional Survey 0 23539 Open 6/19/2008 t Directional Survey 0 23539 Open 6/19/2008 ! C Lis ~ 19321~Induction/Resistivity 3326 23539 Open 1/13/2010 FET, GR, ROP, RPD, RPM, RPS, RPX Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/9/2010 Permit to Drill 2080640 Well Name/No. COLVILLE RIV UNIT CD2-75 Operator CONOCOPHILLIPS ALASKA INC MD 23539 TVD 7355 TION ADDITIONAL INFOR M A Well Cored? ~ r ~ Y,/ tv j 1 Chips Received? d ,~~ Analysis Y. /~L Received? Completion Date 6/1/2008 Completion Status 1-OIL Current Status. 1-OIL Daily History Received? Formation Tops Q N API No. 50-103-20573-00-00 UIC N Comments: Compliance Reviewed By: Date: r~ `J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-064 ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 7. Well Name: CD2-75 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20573-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-213 7/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 390* 390 totals (bbls): 2008 / 3rd 1429 100 0 1529 4 8/22/2008 9/17/2008 CD2-75* 2008 / ath 8626 100 0 8726 10 10/19/2008 10/29/2008 CD2-465 2009 / 1st 0 0 0 0 0 009 / 2nd 0 0 0 0 0 Total Ending Report is due on the 20th volume 10055 200 390 10645 14 of the month following the final month of the quarter. Ex: (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "Leak-off test and freeze protect volumes onl orrect to the best of my knowledge. n d c I hereby certify that the foregoing true a w i ~ ( l ~' ~ D 7 7 (~~ ~° ~ s . ate: 1 ( • Signature: Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-064 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD2-75 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20573-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ^~ 308-213 7/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 390" 390 totals (bbls): 2008 / 3rd 1429 100 0 1529 4 8/22/2008 9/17/2008 CD2-75* zoos / ath 8626 100 0 8726 10 10/19/2008 10/29/2008 CD2-465 2009 / 1st 0 0 0 0 0 2009 / 2nd 0 0 0 0 0 2009 / 3rd 0 0 0 0 0 Total Ending Report is due on the 20th volume 10055 200 390 10645 14 of the month following the final month of the quarter. Ex: (bbls): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "Leak-off test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Date: ~~ (f~e1 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-064 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD2-75 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20573-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-213 7/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 390" 390 totals (bbls): 2ooa / 3rd 1429 100 0 1529 4 8/22/2008 9/17/2008 CD2-75* Zoos / ath 8626 100 0 8726 10 10/19/2008 10/29/2008 CD2-465 2009 / 1st 0 0 0 0 0 2009 / 2nd Total Ending Report is due on the 20th volume 10055 200 390 10645 14 Ex: of the month following the final month of the quarter (bbls): . July 20 for the second quarter, Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fOUrth quarter. 12. Remarks and Approved Substances Description(s): '"Leak-off test and freeze protect volumes onl nd correct to the best of my knowledge. I hereby certify that the forego in g i s tru e a p / ~ / ~ ~~ Signature: ihJ. ( l.~l Date: 4~ ~ ~O Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 March 19, 200" ~ jdC~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~ MAR ~~~~ f~las~ Ool Gay C®~s. ~, .. P,F.~: z~ A~c~or~g~ ~~~-a(~ 5 ~.a ~-_ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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. The corrosion inhibitor/sealant was pumped March 16th & 17`h, 2009. The attached spreadsheet presents the well name, top of cement depth prior to 1 1ng, an vo umes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~, t~-- Perry Klein' ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD2-72 207-057 SF NA 6" NA 0.85 3/17/2009 CD2-73 208-196 4'S" NA 4'5" NA 21.25 3/17/2009 CD2-75 208-064 SF NA 8" NA 1.70 3/17/2009 CD2-463 207-107 4' NA 4' NA 14.87 3/17/2009 CD2-464 208-082 6" NA 6" NA 1.70 3/17/2009 CD2-465 208-145 19" NA 19" NA 4.25 3/17/2009 CD2-466 208-095 8.5" NA 8'S" NA 1.70 3/16/2009 CD2-467 208-114 SF NA 6" NA 0.85 3/16/2009 CD2-468 208-180 SF NA 5" NA 1.70 3/17/2009 CD2-469 208-122 SF NA 7" NA 0.85 3/17/2009 CD2-470 208-129 SF NA 8" NA 1.70 3/17/2009 C] ;.~+ ~ t_.1....~.~ ALASSA OIL AI~TD GAS COI~TSLRQATIOI~T COM1rIISSIOI~T Tim Schneider Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-75 Sundry Number: 309-,1-Y~~~S J ~ Dear Mr. Schneider: r: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907j 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. S t Chair DATED this Z ~ day of January, 2009 Encl. /~ lP '~n~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION J,~~ ~ ~~~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~4t~~k~ Qil ~~~ ~rtn~ ~..~..~~_ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ V®r~~ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^/ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^/ Exploratory ^ 208-064 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20573-00 ' 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 NO Q CD2-75 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075, ADL 387207, ASRCNPRA02~ RKB = 37' Colville River Field /Alpine Oil Pool - 12. PRESENT WELL GONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 23539' 7355' • Casing Length Size MD ND Burst Collapse CONDUCTOR 77~ 16" 114' SURFACE 3316' 10-3/4" 3353' PRODUCTION 15665' 7-5/8" 15702' LINER 8340' 4-1/2" 21202' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1 /2" L-80 12882' Packers and SSSV Type: Packers and SSSV MD (ft) Baker S-3 X 7 5/8" Premier Packer Packer = 12734' Camco TRMAXX-5E SSSV Nipple SSSV = 2196' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Early February 2009 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tlm SChnelder Title: Production Engineer `._.._- Signature / ~ ~~ Phone 265-6859 Date ~ /~-~jrj Commission Use Onl Sundry Number: D/ ~j~ Conditions of approval: Notify Commission so that a representative may witness G, Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: ~~~ ~'~ APPROVED BY ~~ / Approved by. COMM. S NER THE COMMISSION Date: i STATE OF ALASKA a Form 10-403 Revised 06/200 ~ ~ I` ~ !~, i~~~' ~~~~ubmit i Dupl/i~at~ ~} n.n.. • ~J Overview: CD2-75: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "A" sand.' This will increase the wells production rate. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU at least ten clean insulated frac tanks. Load tanks with Seawater from CD2 injection manifold. (approximately 4500 bbls are required for the treatment) 2. Rig up Schlumberger pumping services equipment and stab the 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 9000 psi 4. Pump the 300 bbl Breakdown with YF125ST fluid with L-65 Scale inhibitor (50 gpt). Bring pumps up to maximum rate ASAP. SD and obtain ISIP 8~ Pc. a. Pump Schlumberger's schedule at 20-25 BPM with a maximum pressure of 8000 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment using Little Red's pump truck. b. 4 Stages of 2,4,7 PPA ramped containing: • 1260 bbls dirty YF125ST dropping to 1220 bbls for the remaining three stages (3660 bbls) • 611 Mlbs. -16/30 white sand • 40 -100 bio-balls via the ball drop after each 7 ppa stage (180 balls total) • Flush with 50 bbls YF125ST; 50 bbls WF125, and 91 bbls diesel (191 bbls tubing volume to mid liner depth) . `~~\~ WNS ~ CD2-75 r ~ t,~ fyll~~~i 11~fi~35 t ~ MdX We l A ttrl h Utes ` ngle & MD A TD ~ .t~tSii:3 Si i A V ~ - 1 ,MD (ftKB) eld Name Wall Status Prod/ln Type 501032057300 .ALPINE PROD 92.7.5 16,816 85 _ Act Btm (ftKB) 23,539 0 Comment H2S (ppm) Data Annotation Entl Date KB-Grd (R) Rig Release Dat v ne aRl o ovs nyr<oofl 1o7 t3 SSSV'TRDP 0 711!2008 (Last WO I ~ 3635 6/2/2008 ,._ y e a,gg._n y_g},,c . Z _ .__. Schematic Anu gM. h al _. Annotation De th ftKB Entl Date Annotation P ( ) End Date - ~ Last Tag: Rev Reason: GLV CIO, ADD FISH ! 1 111 8/20 0 8 Casing Strings __ CONDUCTOR, '~ i; '.. . Casing Description Stnng 0... .String ID ... Top (ftKB) Set Deplh ((... Set Depth (ND)... String Wt... Stnng ... String Top Thrd 36~11a _ ;, CONDUCTOR 16 15.250 36.0 114 0 114 0 65.00 H-40 Welded ' :' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd "'. SURFACE 10 3!4 9.950 36.0 3,353.6 2 390.1 45-50 L 80 BTCM_ SAFETY VLV, '~ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String W1... Stnng ... String Top Thrd 2196 INTERMEDIATE 7 5/8 6.875 33.3 15 702.0 7,370.3 2970 L 80 BTCM ~. ~ ~ Casing Description String O String ID _. Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wl... Stnng String Top Thrd SURFACE, a LINER PERF PUPS 4 112 ~~ 3.958 15,198.6 23,539.0 7,355.4 12.60 L 80 IBT 36-3354 ,. _ .: Li t i . -. _. ,____ Gns uFT, - - _ - - - nerpe a ls__. _ _... ' __ __ _... ...._ --- 5,670 'TOP Depth Pu K~ (rVD) 'Top Inc! Top (ftKB) I 1ftK6) I. (°) I Hem Descnption Comment ID (ir cqs uFT, 15,198.61 7,283.6 78-38iSLEEVE 'HR' Liner Setting Sleeve 575' ID 5.75(; _ _. tr,m _. _ _..... ___ 15,211 OI 7,286.21 78 47 iX0 XO - 5 1/2' Hyd 521 Pin X 5 1 2" BTC 4.90C GAS LIFT. ~ ~ _--- -_ - 1267s -- 15,2128' 7,2868 78.491 NIPPLE "RS"Nipple (4-89'ID) 4.89C _ _ -_ Flsn, t27oo-- 15226.4 7,2894 78.59'1X0 XO-51/2"BTCX41/2'IBT - - - 3.94C Packers, 12,]34 -.. I - __ NIPPLE tzet3 -. -- - Tubing Strings _ _ LOC Sue, _ _ _ Tubing Des npbon i String O Str g ID ... Top (ftKB) Set Depth (f _ Set Depth (TVD) .. Stnng WI._ Stnng ._ String Top Thrd 1ge5] TUBING I 3 112 2 992 ~ 0 0 12 882 1 6 517 7 ~ 9 30 ~ L 80 ~ EUE-8 Rd WLEG. 12885 ~'~ - PRFJT. lion Details _. _ _ ~_ p _ - _ 1378 tP1R3FlT ~\ Olrl a (TVD) ITop Intl PRF JT 1393513943 -` ~ To ftKg Top Depth/ 1 141561a 160 ~. P ~ f _ (ftKB) I (°) Nem D pt n C nt _ ID (n) PRF JT. ~ ~ 128 4 128.414 0.30 Cross Over XO 3 1!2' EUE (Pin) X 4 112 IBTM(Box) 2 99"e 14,3]]-16,362 - - __ PRF JT. _ ~ ~ .; 2,195.9 1875.3 58.93 SAFETY VLV TRDP~ 3 1!2' Camco TRMAXX-SE SSSV w/ Profle 2.81"e 14,59914,600 ,,.. " -- i -. _ - PRF JT. 12,733.9 6,455.4'. 64.76 Packers Baker 3.5" X 7 5/8' Premier Packer 2.87C 1a,a1 514,821 _ _ PRFJT._ 12813.3 648891 - - ts,o35-t5p39 ~ ~ 65.2511 NIPPLE 35" HES "xN' Nipple 3.96' OD X 2.813' ID wl 2 75' No Go 2.813 12 881.1 6 517 { 1 65 471 WLEG Wlre Line Entry Gu de 2 992 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc. 1525615261- TOp Intl PRF JT ftKB 54]PRF4 T, Top (ftK8)T( De)th (°) Descnption Comment Run Date ID (in) 15597-1 s.]o2 -. 12.700-0 6440 81 64 591FISH 1' HES SPG 11!8!2008 0.000 OTERME00\TE, ~. Pel'f0ratlOns _ ~ - _ - _ 3315,]02 ,: '•' _______ ____- _ _.. --_ ........: _ -_ _ -.. PRF JT, ~ ~ Sh t 159I2~15,917- Top (TVD) Btm (TVD) D s PRFJT,-_ _ ~ T p(ftK6) Bt (ftKB) (ftKB) (HKB) Z e Date (sh Type _ C mment_. _ ts,l2eas,133 ~ ~ 13 760.7 13 765.5 6 863 3 6,865.0 ALB96 CD2-75 15/30!2008 6 0 PRFJT PRF JT,- _ -. ~ J. 13 938 61 13,943 4 6,926.3 6,927.9 ALB96, CD2-75 15/30/2008 6 0 PRF JT 16345-16,350 r - . -- - - -- = 14,155.6 14,1604 6,999.2 7,000.8 ALB96, CD2-75 5/30/2008 60 PRF JT PRF JT. _ _ --___ t 6,56716,572 ~ ~ 14,377.1 14,381.8 7,069.8 7,071.2 ALB96, CD2-75 5/30/2008 6 0 PRF JT ___ PRFJT,_ _. - - 14,598.8 14 603.5 7,135-3 7,136.6 ALB96. CD2-75 5/30/2008 6.0 PRF JT 16,760-16,785 _-.._. 14816.1 14,820.9 7,194.1 7,195.4 KUPD, CD2-75 5/30/2008 60 PRFJT PRFJT,_ _ ~ ~_..._. ,- __ 15,995-t7,ooo 15 034.5 15,039.31 7,247.2 7,248.4 ALPD, CD2-75 5/3012008 6 0 PRF JT I 15,255.8 15,260 6 1],2101],215 ' PRFJT, ~ ~ _. 15897 3 15,7pp t) 7 295.2 7,296.2 ALPD, CD2-75 5/3012008 6.0 PRF JT PRF JT, 7,335.0 7,335.8 ALPC, CD2-75 5/30/2008 6.0 PRF JT n,a3o-»p35 I 7,369-8 7,370.3 ALPC, CD2-75 5/30/2008 6.0 PRF JT PRF Jr. _ ~ _ _.'~ nss^.-17,656 ~ ~"" 15,912.3 15 917 01 7,391.9 7,392.5 ALPS, CD2-75 5/30/2008 6 0 PRF JT - PRFJT, _ ~ (_.__ 16,128.5 16,133.2' 7,408.3 7,408.7 ALPA, CD2-75 5/30/2008 6 0 PRF JT 17,872-17,en _ t 16,345.2 16,350.5 7,419.8 7,419.9 ALPA, CD2-75 5/30/2008 6 0 PRF JT 18,091PR8,09G ~ ~" 16,567.1 16871.9f 7 415.91 7,415.7 ALPA, CD2-75 5!30/2008 6 0 PRF JT 7,408.3 ALPA, CD2-75 5/3012008 6 0 PRF JT -- _.__-~ PRF JT, _ 16,780.0 16784.7 7,408.5 18,304-18,309 - -' ~ - - 16 994.8 16,999.6 7 404.0 _ -~ PRF JT. 7,404.0 ALPA, CD2-75 5/30/2008 6 0 PRF JT 18,525-18,529 17, 09 17, 14 6 7 40 5~~ PRF JT _ 17,430.0 17,434.8 7 405.01 7402.8 ALPA, CD2-75 5/30!2008 6 0 PRF JT 17,651 2 17,655.9 7,399.31 7 404-9 ALPA, CD2-75 5130/2008 6 0 PRF JT ,. _. 18,]43-18,]48 - tBSSZ-Ra9ei - 17,872-1 17876.8 7,398.7 7399.1 ALPA, CD2-75 5/30/2008 60iPRFJT 7,398.7 ALPA, CD2-75 5/30!2008 6 OPRF JT >.. - ALPA, CD2-75 5/30/2008 i 6 0 PRF JT 19.18 PRF JBS -.. ~ L. 18,303.7 18,308.5 7,397.0 7 397.0 - 18,5248 18,5394 7,393.9 7393-8,ALPA, CD2-75 5/30!2008 I 6.OjPRF JT t9,boz-19,aos (ALPA, CD2-75 5/30/2008 6 OPRF JT PRF JT.-- ~ ~ < 18,743.1 18,747.8 7,387.1 7387.0 ~IALPA, CD2-75 5/30!2008 6 O~PRF JT - -- 19,622-19,626 1 _.~ PRF JT, 18 962.2 18,967.0 7,385.9 7,385.9'IALPA, CD2-75 5/30!2008 6 0 PRF JT 19,84219.647-- - - ~~-- 19,1804 19,185.2 7,383.2 7,383.2~ALPA, CD2-75 5/30/2008 60 PRF JT PRF JT. __-- -. ~ 19,401.61 19 406.4 7,384.9 7,384.8ALPA, CD2-75 5/30/2008 6 0 PRF JT 20,060-20,065 ' PRFJT, -.-_ ~ 19621.6 19,626.4 7,380.1 7,379.9 ALPA CD2-75 5/30/2008 60 PRFJT 20,2]5-20,281 - I - - -- 19842.0 19,846.8 7,376.1 7,376.0 ALPA, CD2-75 5/3012008 6 0 PRF JT PRFJT._ _-_. - "_-' 20,490-20695 I 20 060.3 20,065.1 7,375.2 7,375.2 ALPA, CD2-75 5/30/2008 6 0 PRF JT _ __. __ PRFJT, __ __ i 20,276.0 20,280.7 7,373.6 7,373.6 ALPA, CD2-75 5/30/2008 6 0 PRF JT 2o,7t v2o,7ts t -- - 20,489.9 20,494 7 7,371.4 7,371.4 ALPA, CD2-75 5/30/2008 6 0 PRF JT PRF JT. __ _ -__- 20,929-20,933 ~ 20,711.3 20,716 1, 7,369.3 7,369.2 ALPA, CD2-75 5/3012008 6 0 PRF JT -. PRF JT. __ 20,928.6 20 933 4' 7,365.1 7,365.2 ALPA, CD2-75 5/30/2008 6.0 PRF JT 21,150-21,1 s5 - - - 21,150.3 21,155.11 7,366.4 7,366.3 ALPA, CD2-75 5/30/2008 6 0 PRF JT i i ~ --- ! t ~ ~ MandretDetails-_ ~` Top Depth Top Port (ND) Intl OD Valve Latch Srze TRO Run Stn Top (ftKB) (HK8) (°) Maka Motlel (in) 5 Type Type (~n) (psi) Run Date Comm... 1 5,6704 3,397.5,6671 Camco KBMG 1 Gas Lilo DMY BK-5 0 006/1/2008 LINFR PERF 2 10,771.5 5,604.1 64-86 Camco 'KBMG 1 Gas Lift DMY BK 5 0 0 0 6/1/2008 15,199-za 535 ~ ~ r I iKBMG 1 Gas Lift _ OV BEK... 1/4 ..006!3/2008 ' ! 3 12,675.71 6,430.4 64-46 Camco TD, 23,539__ _- -. - --.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR QISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-064 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-75 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20573-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-213 7/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 390'` 390 totals (bbls): 2008 / 3rd 1429 100 0 1529 4 8/22/2008 9/17/2008 CD2-75'` Zoos / 4th 8626 100 0 8726 10 10/19/2008 10/29/2008 CD2-465 2009 / 1st 2009 / 2nd -Total Ending Report is due on the 20th volume 10055 200 390 10645 14 of the month following the final month of the quarter. Ex: (bbls>: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-off test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. / '~ - ~ Date: / f ~~ si nature: ~ g . Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOAI..- 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ 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. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ~ Exploratory ^ 208-064 3. Address: StraGgraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20573-00 7. KB Elevation (ft): 9. Well Name and Number: KBE = 37' RKB CD2-75 • 8. Property Designation: 10. Field/Pool(s): ADL 380075, ADL 387207, ASRCNPRA02 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 23539' ' feet true vertical 7355' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 7T 16" 114' INTERMEDIATE 3316' 10-3/4" 3353' SURFACE 15665' 7-5/8" 15702 SURFACE 8340' 4-1/2" 21202' SURFACE Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3 1/2" L-80 tubing to 12882' Packers &SSSV (type & measured depth) Baker S-3 X 7 5/8" Premier Packer @ 12734' Camco TRMAXX-5E SSSV Nipple @ 2196' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2476 1787 12 NA 975 Subsequent to operation 1968 1017 261 1836 265 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 proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Tim Schneider Printed Name Tim Schneider Title Production Engineer Y 2 Signature ~/~~ Phone 265-6859 Date l - ~ -b (/ fl ~d r Pre red b Jeanne L. Haas 263-4470 ./SD r~.•i.,~ Form 10-404 Revised 04/2006 ~ ~ ~' bmit Original Only WSR -Well Service Report • • Page 1 of 1 Well Service Report Yell ..lob Scope C.PAI Rep CD2-75 Scale Inhibition Christensen, Bob Date Daily ~~'ork Unit Number 11/10/2008 32 Nehvork # Daily Cost Cum Cost Company Unit Supers=isor 10236879 $46,814 x$46,814 LRS-~ FARNHAM Initial & Initial T/I/O =1200/ 1475/ Final 280 Final T/UO = 1475/ Field: ALPINE Pressures: 2284/ 832 A AND AL Z .PUMPED 185 BBLS DEAD CRUDE CONTAINING 7.4 GALLONS OF M209 AHEAD OF TREATMENT. PUMPED 5 STAGES CONSISTING OF 4 BBLS DEAD CRUDE CONTAINING 0.4 24 hr. GALLONS M209 AND 18 GALLONS WAW-5206 FOLLOWED BY 28 BBLS Summary SW CONTAINING 178 GALLONS SCW-3001 FOLLOWED BY 4 BBLS DEAD CRUDE CONTAINING 0.4 GALLONS M209 AND 18 GALLONS WAW-5206 FOLLOWED BY 108 BBLS DEAD CRUDE CONTAINING 11.4 GALLONS M20 . EACH STAGE FOLLOWED BY 7/8" BIO-BALLS FOR DIVERSION. ST_4RTTIME OPERATION 11:40 AM Pump treatment, abort job after 5 stages due to increased IA pressure. F'lu'rd Type To Well From 1~e11 Non- recoverable Note http://anc402/weq/worklog.aspx?ID=85DCOAADB8BE4CAEAAF 189DE 1 DSF 15C 1 &Date=11 /... 12/10/2008 ~-~ ~~ WNS • CD2-75 ~Q~O1'(1~1~~~ 1 Well Attributes Max An le & MD TD A ~ .tie i, i~ J Wellbore APIIUWI Field Name Well Status Prodllnf Typo Intl (°) MD (ftKB) Act Bhn (StKB) 501032057300 ALPINE PROD 92.75 16,816.85 23,539.0 Comment H23 (ppm) Date Annotation End Date KB-t6rd (ft) Rig Release Date SSSV: TRDP 0 7/1/2008 Last WO: 36.35 6/2/2008 Well COnfi HORIZONTAL-GD2-7 s~nemar~~- A 5 11/1912 doal 0081:07.13 AM Annotation Depth (RKB) End Date Annotation End Date - - rn -- Last Tag: Rev Reason: GLV C/O. ADD FISH 11/18/2008 . ~. YS,n~ ; Casio Strin s CONDUCTOR, __ as-114 '~ ~ ~ _ Casing Deacrlption String 0... String ID .- lop (ftl(B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... Stdng Top Thrd 00 H-40 Welded 0 114 0 114 0 65 CONDUCTOR 16 15 250 36 ~! ~ '", Casing Deacrlption String 0.. . . String 10 ... . Top (RKB) . Set Depth (f... S . et Depth (TVD) ~~~ . String Wt... String ... String ToP Thrd ~ ~ SURFACE 103/4 9.950 36.0 3,353.6 2,390.1 45.50 L-80 BTCM SAFETY VLV, ~ Casing Deacrlption String 0.. . String ID ... Top (kK6) Set Depth (f... S et Depth (7VD) ... String Wt... SMng ... String lop Thrd 2.1~ ~ i INTERMEDIATE 75/8 6.875 33.3 15,702.0 7,370.3 29.70 L-80 BTCM ~' I ~ ~ Casing Description String 0.. . String ID ... Top (RKB) Set Depth (f... S et Depth (TVD) ... String Wt... SMng ... Strng Top Thrd SURFACE, ' J ~;. LINER PERF PUPS 41/2 3.958 15.198.6 23.539.0 7,355.4 12.60 L-80 IBT 36-3.354 V' GAS LIFT . Liner Deta11$ , 5,670 Top Depth f , (7VD) lop Intl , Top (ft1C8) (~B) (°) I tem Descriptio n Comment ID (In) GAS LIFT, 15,198.6 7,283.6 78.38 S LEEVE "HR" Liner Setting Sleeve 5.75" ID 5.750 10,771 GAS LIFT 15,211.0 7,286.2 78.47 X O XO - 5 1/2" Hyd 521 Pin X 5 1.2" BTC 4.900 , 12,676 15,212.8 7,286.6 78.49 N IPPLE "RS" Nipple (4.89" ID) 4.890 FISH, 12,]00 15,226.4 7,289.4 78.59 X O XO-5 112" BTC X4 1/2" IBT -- 3.940 Packers, 12,734 NIPPLE,12,813 Tubin Strin S LOG SUB, Tubing Deacrlption String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 12,as7 4;=~ (-Rn EUE-8 Rd 1 6 517 7 9 0 12 882 TUBING 31/2 2 992 0 WLEG, 12,891 PRFJT, 13,787-73,785 , . . . . . , __ COm letion Details PRF JT, Top Depth __ 13,938-73,943 (iT/D) TOp Intl PRF JT, 14,156-14,160 Top (RKB) (RKB) (°) I tem Deacrlptio n Comment ID (in) PRF JT, 74 377-14,382 12$.4 128.4 0.30 C ross Over XO - 3 1/2"EUE (Pin) X 41/2" IBTM (Box) 2.992 , PRFJT, 14,599-14,604 2,195.9 1,875.3 58.93 S AFETY VLV TRDP: 3 1/2" Camco TRMAXX-5E SSSV w/ Profile 2.812 PRFJT, 14,H76-14,821 _ 12,733.9 6,455.4 64.76 P ackers Baker 3.5" X 7 5/6" Premier Packer 2.870 PRFJT. ~ 15,035-15,039 12,813.3 6,488.9 65.25 N IPPLE 3.5" HES "XN" Nipple 3.96" OD X 2.813" ID w/ 2.75" No Go 2.813 12,881.1 6,517.2 65.47 WLEG Wire Line Entry Guide 2.992 `, Other In Hole Wireline retrievable lu s, valves, um s fish etc. PRF JT, Top Depth 15,256-15,261 (TVD) Top Intl PRF J7, 477-15 482 - 15 Top (RKB) (RKB) (°) Description Comment Run Date ID (In) , . 12 700.0 6 440.8 64.59 F ISH 1" HES SPG 11/8/2008 0.000 PRF JT, , , 75,697-15,702 NTERMEDIATE, 33-15 702 PerfOratlons , PRFJT, Shot 75,972-15,917 Top (TVD) Btm (TVD) Dena PRFJT lop (RKB) Btm (fdCB) (RKB) (ftK8) Zone Date (sh-- Type Comment , 16,128-16,133 13,760.7 13,765.5 6,863.3 6,865.0 A L696, CD2-75 5/30/2008 6.0 PRF JT PRF JT, 16 345-16 350 13,938.6 13,943.4 6,926.3 6,927.9 A LB96, CD2-75 5/30/2008 6.0 PRFJT , , PRFJT 14,155.6 14,160.4 6,999.2 7,000.8 A LB96, CD2-75 5130/2008 6.0 PRF JT , 16,56]-ifi,572 14,377.1 14,381.8 7,069.8 7,071.2 A LB96, CD2-75 5/30/2008 6.0 PRF JT PRFJT, 16,780-16,785 14,598.8 14,603.5 7,135.3 7,136.6A L896,CD2-75 5/30/2008 6.0 PRFJT PRFJT, 14,816.1 14,820.9 7,194.1 7,195.4 K UPD, CD2-75 5/30/2008 6.0 PRFJT 16,995-1],000 15,034.5 15,039.3 7,247.2 7,248.4 A LPD, CD2-75 5/30/2008 6.0 PRFJT PRFJT, n,vo-n,2ls 15,255.6 15,260.6 7,295.2 7,296.2 A LPD, CD2-75 5/30/2008 6.0 PRFJT 15 477 4 15 482 2 7 335 0 7 335 8 A LPC CD2-75 5/30/2008 6.0 PRFJT PRFJT, . . , . , . , . , 17,430-17,435 15,697.3 15,702.0 7,369.8 7,370.3 A LPC, CD2-75 8130/2008 6.0 PRFJT PRFJT, 17,651-17,656 15,912.3 15,917.0 7,391.9 7,392.5 A LPS, CD2-75 5/30/2008 6.0 PRF JT PRFJT, 16,128.5 16,133.2 7,408. 3 7,408.7 A LPA, CD2-75 5/30/2008 6.0 PRF JT n,en-17,an 16,345.2 16,350.5 7,419. 8 7,419.9 A LPA, CD2-75 5/30/2008 6.0 PRF JT PRFJT, 18,091-18,096 16,567,1 16,571.9 7,415. 9 7,415.7 A LPA, CD2-75 5/30/2008 6.0 PRFJT PRFJT, 18 304 18 309 16,780.0 16,784.7 7,408. 5 7,408.3 A LPA, CD2-75 5/30/2008 6.0 PRFJT , - , PRFJT 16,994.8 16,999.6 7,404. 0 7,404.0 A LPA, CD2-75 5/30/2008 6.0 PRFJT , leszs-leszs 17,209.8 17,214.6 7,402. 5 7,402.8 A LPA, CD2-75 5/30/2008 6.0 PRF JT PRFJT, 18 743-18 748 17,430.0 17,434.8 7,405. 0 7,404.9 A LPA, CD2-75 5/30/2008 6.0 PRF JT , , PRFJT 17,651.2 17,655.9 7,399. 3 7,399.1 A LPA, CD2-75 5/30/2008 6.0 PRFJT , 18,962-18,967 17,872.1 17,876.8 7,398. 7 7,398.7 A LPA, CD2-75 5/30/2008 6.0 PRF JT PRF JT, 18 091 0 18 095 8 7 398 4 7 398 4 A LPA CD2-75 5/30/2008 6.0 PRF JT 19,780-19,185 , . , . , . , . , PRFJT, 18,303.7 18,308.5 7,397. 0 7,397.0 A LPA, CD2-75 5/30/2008 6.0 PRF JT ta,4oz-1s,4os 18,524.6 18,529.4 7,393. 9 7,393.8 A LPA, CD2-75 5!30/2008 6.0 PRFJT PRFJT• 19,fi22-19,626 18,743.1 18,747.8 7,387. 1 7,387.OA LPA,CD2-75 5/30/2008 6.0 PRFJT PRFJT, 16,962.2 18,967.0 7,385. 9 7,385.9 A LPA, CD2-75 5/30/2008 6.0 PRF JT 1e,a12-19,847 19,180.4 19,185.2 7,383. 2 7,383.2 A LPA, CD2-75 5/30/2008 6.0 PRF JT PRF JT, 19 401 6 406 4 19 7 384 9 7 384 8 A LPA CD2-75 5/30/2008 6.0 PRF JT 2°.oso-2o.ofis , . , . , . , . , PRFJT, 19.621.6 19,626.4 7,380. 1 7,379.9 A LPA, CD2-75 5/30/2008 6.0 PRF JT zo,z76-zo,zal 19,842,0 19,846.8 7,376. 1 7,376.0 A LPA, CD2-75 5/30/2008 6.0 PRFJT PRFJT, zo,a9azo,aes ZO,O6O.3 20,065.1 7,375. 2 7,375.2 A LPA, CD2-75 5/30/2008 6.0 PRFJT PRF JT, 716 zo 711 zo 20,276.0 20,280.7 7,373. 6 7,373.6 A LPA, CD2-75 813012008 6.0 PRF JT , - , PRFJT 20,489.9 20,494.7 7,371. 4 7,371.4 A LPA, CD2-75 5/30/2008 6.0 PRFJT , 20,929-20,933 20,711.3 20,716.1 7,369. 3 7,369.2 A LPA, CD2-75 5/30/2008 6.0 PRFJT PRFJT, z1 1so-zt lss 20,928.6 20,933.4 7,365. 1 7,365.2 A LPA, CD2-75 5/30/2008 6.0 PRF JT , , 21,150.3 21,155.1 7,366. 4 7,366.3 A LPA, CD2-75 5/30/2008 6.0 PRFJT Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latoh Size 7R0 Run Stn Top (kKB) (RKB) (°) Make Motlel (In) Serv Type Typo (in) (psi) Run Date Comm... 1 5,670.4 3,397.5 66.71 Camco KBMG 1 Gas Lift DMY BK-5 0 0.0 6/1/2008 LINER PERF 2 10 771 5 5 604 1 64 86 Camco KBMG 1 Gas Lift DMY BK-5 0 0.0 6/1/2008 PUPS, , . , . . 15,199-23,539 3 12 675.7 6 430.4 64.46 Camco KBMG 1 Gas Lift OV BEK 1/4 0.0 613/2008 TD, 23,539 , , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-064 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-75 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20573-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 308-213 7/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 390* 390 totals (bbls): 2008 / 3rd 1429 100 0 1529 4 8/22/2008 9/17/2008 CD2-75" 2008 / 4th 2009 / 1st 2009 / 2nd Total Ending Report is due on the 20th volume 1429 100 390 1919 4 of the month following the final month of the quarter. Ex: (bbls): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-off test and freeze protect volumes onl t to the best of my knowledge. and cor rec I hereby certify that the foregoing is true ~~ ~~ /~l Signature: _~.(~.L,~IX~C! Date: f:x/3(D~ Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Maunder, Thomas E (DOA) Page 1 of 3 From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.comJ Sent: Tuesday, September 16, 2008 9:13 AM To: Maunder, Thomas E (DOA) Subject: RE: Update on CD2-470 operations Attachments: Patrick.J.Reilly@conocophiltips.com.vcf Thanks Tom. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly@conocophillips.com ao~s-~a~ --~ ~o~-o~~l From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov) Sent: Tuesday, September 16, 2008 8:35 AM To: Galiunas, Elizabeth C; Reilly, Patrick J Subject: RE: Update on CD2-470 operations Pat and Liz, I did receive the original message and have placed copies in the file. By my read of the message, I did not think a reply was needed. The plans forward appear appropriate. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.mm] Sent: Tuesday, September 16, 2008 8:12 AM To: Maunder, Thomas E (DOA); Reilly, Patrick J Subject: FW: Update on CD2-470 operations From: Galiunas, Elizabeth C Sent: Friday, September 05, 2008 11:19 AM To: 'Maunder, Thomas E (DOA)'; Alvord, Chip; Chambers, Mark A; Noel, Brian Cc: Regg, lames B (DOA); Davies, Stephen F (DOA) Subject: Update on CD2-470 operations Hi, Tom, Currently Doyon 19 is drilling the lateral on CD2-470. It is believed that we set surface casing in a sandy horizon of the lower C40 sand. I have attached the logs from CD2-470 run on Intermediate and the Alpine 1 B log. Based on our surface LOT (17.0 ppg) and the Annular LOT (16.5ppg) we will not permit this well for annular disposal operations. The Surface LOT does indicate shoe integrity. The casing operations went smooth and the cement job according to plan. We believe we have the sandy horizon behind casing and cement. I have attached the Surface LOT and the annular LOT. We are planning to resume annular disposal operations on CD2-75 and closely monitor the OA on CD2-470. If there is any indication of pressure communication, annular disposal 9/16/2008 • . Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, September 05, 2008 11:19 AM To: Maunder, Thomas E (DOA); Alvord, Chip; Chambers, Mark A; Noel, Brian Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: Update on CD2-470 operations Attachments: CD2-470 Attachments for AOGCC.pdf Hi, Tom, ~ ~~~~ «~ Page 1 of 2 Currently Doyon 19 is drilling the lateral on CD2-470. It is believed that we set surface casing in a sandy horizon of the lower C40 sand. I have attached the logs from CD2-470 run on Intermediate and the Alpine 1 B log. Based on our surface LOT (17.0 ppg) and the Annular LOT (16.5ppg) we will not permit this well for annular disposal operations. The Surface LOT does indicate shoe integrity. The casing operations went smooth and the cement job according to plan. We believe we have the sandy horizon behind casing and cement. I have attached the Surface LOT and the annular LOT. We are planning to resume annular disposal operations on CD2-75 and closely monitor the OA on CD2-470. If there is any indication of pressure communication, annular disposal operations will be suspended on CD2-75. Call with any questions, ~ c~~~--~Cp y ~~ G ~ ~~~f_~.~~p,~ ~ ~`~ Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441 X871 ~~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 25, 2008 3:49 PM To: Galiunas, Elizabeth C; Alvord, Chip; Chambers, Mark A; Noel, Brian Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: CD2-470 Operations: Surface Hole Issues Liz, Thanks for the information. Interesting that the shoe of CD2-75 is over 850' from CD2-470. At lunch you mentioned that the wells might have been in the plain of minimum horizontal stress. Do !have that correct? Was pressure seen on any of the other wells proximate to CD2-75? Are there any other surface bbls that lie in the minimal horizontal stress plain? I look forward to your reply. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Monday, August 25, 2008 3:37 PM To: Maunder, Thomas E (DOA); Alvord, Chip;. Chambers, Mark A; Noel, Brian Subject: CD2-470 Operations: Surface Hole Issues Hi, Tom, On August 24th at 15:15 hrs, surface TD was reached on CD2-470 with a mud weight of 9.9 ppg. The rig began 9/8/2008 Page 2 of 2 a wiper trip checking connections for flow. The connections up to stand 17 (2047' MD) were static. At stand 17, slight flow was observed. The well was monitored for 10 minutes, with slight flow continuing. The mud weight in and out at this point was 9.7 ppg. The mud weight was increased to 10ppg with slight flow. There was no gas cut mud or other hydrocarbons in the mud returns. The BHA was run back to bottom where the mud weight was increased to a 10.2 ppg. On Sunday, CD2-75 (308-213) was used for annular disposal for the first time with class 2 fluids from CD2- 470. CD2-470's TD is 867ft away from the surface shoe of CD2-75 (see attachment for details). I have also attached a detailed summary of all the injections on CD2-75. It was suspected that annular disposal on CD2-75 communicating with CD2-470. The decision was made to bleed off the annulus on CD2-75 back to a tiger tank. Initially the pressure was 1100 psi on the annulus. A total of 64 bbls of diesel and 9 bbls of water were bleed back on CD2-75's. Meanwhile, the gain rate on CD2-470 decreased and reached static. This morning, CD2-470 was monitored from 0400 - 0530hrs with no gain while circulating at 6 bph. The pumps were shutoff and the well was static for over 20 min. The rig began to pump out at this point monitoring each connection for flow. At around 8 AM, the decision was made to bull head diesel freeze protect on CD2-75 with 8 stands off bottom on CD2-470. While monitoring CD2-470, 54 bbls of diesel was pumped down the annulus on CD2-75. CD2-470 remained static through the pumping operations. Currently the pumping is complete down the annulus on CD2-75 and CD2-470 is still static. Once the rig was confident there was no flow from CD2-75, the rig began to pump out of the hole. Currently we are still coming out of the hole and is planning to rig up to run surface casing and cement operations once out of the hole. Since it appears CD2-75 is in communication with CD2-470, annular disposal operations on CD2-75 will be suspended indefinitely and CD1-19a will be utilized for disposal. Attached is the current rig surveys, CD2-75 injection summary, the Well View daily operations report up to midnight on 8/24/08, and details on surface shoe distances. Please call with any comments or questions. We will keep the AOGCC informed of any findings, like the Surface LOT and Annular test on CD2-470. Regards, Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441 X871 9/8/2008 • • Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, August 26, 2008 11:12 AM To: Maunder, Thomas E (DOA); Alvord, Chip; Chambers, Mark A; Noel, Brian Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: CD2-470 Operations: Surface Hole Issues Attachments: CD2-75 SurfaceCasingView updated 8-26-08.pdf Tom, Page 1 of 2 The comment about CD2-75 being in the plan of maximum horizontal stress is a stretch. One would have to take the leap of faith and assume the stress plane is continuous all the way from Alpine up the the Qannik up an additional 1500' TVD to 2400' TVD. We are not yet convinced this is possible. I attached an updated quarter mile surface casing plot, with a line indicating the maximum horizontal stress plane in the Alpine. Last night, the rig did get casing to bottom with no issues and a good cement job. I will keep you posted on the LOT and the Annular test. Thanks, Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441-4871 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 25, 2008 3:49 PM To: Galiunas, Elizabeth C; Alvord, Chip; Chambers, Mark A; Noel, Brian Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: CD2-470 Operations: Surface Hole Issues Liz, Thanks for the information. Interesting that the shoe of CD2-75 is over 850' from CD2-470. At lunch you mentioned that the wells might have been in the plain of minimum horizontal stress. Do I have that correct? Was pressure seen on any of the other wells proximate to CD2-75? Are there any other surface bbls that lie in the minimal horizontal stress plain? I look forward to your reply. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Monday, August 25, 2008 3:37 PM To: Maunder, Thomas E (DOA); Alvord, Chip; Chambers, Mark A; Noel, Brian Subject: CD2-470 Operations: Surface Hole Issues Hi, Tom, On August 24th at 15:15 hrs, surface TD was reached on CD2-470 with a mud weight of 9.9 ppg. The rig began a wiper trip checking connections for flow. The connections up to stand 17 (2047' MD) were static. At stand 17, slight flow was observed. The well was monitored for 10 minutes, with slight flow continuing. The mud weight in 9/8/2008 r.' ~OI'1CKt3rr 11~11rJS Project: Western North Slope Site: CD2 Alpine Pad C D2_75 Well: CD2-75 Wellbore: CD2-75 Q u a rte r M i l e View CD2-75 0 550 iZs'`~ j o~ ~ ,~ - ~ ~ W I !.J 1 ___. ___- --_ r \ 0 -,- 2 59~ ~ GO ~,/ ~ ~ ~ 'I n ~ I N ~ ~~ _ I / I ~ c ~ •~l ~ ~ -550 ~ ~ , ~ ~ .-. + -- ~ z 1100 ~~ a~ 5 S Cs ircle ~ \w ! , L ~ '~ O ~" oo h (n '. -1650 ~~ ,~~~ GO? - ~ ~ 15 `, G~1~ -2200 ~ ' ~.. ~~~~~ '~,. ~ j ~0~ 6A~'~ ~ , , G~'b~ GOZ~ % ~ c~A~ G02 '~ ~~ ~ ~ G~ ~ ~05~.~> 2750 ~~~'= -3850 ~-%3300 22 - - 00 -1650 -1100 -- - -550 0 550 , G~~ ~~~ ~ G~~' West(-)/East(+) (550 ft/in) • • • Yage 1 of "l Maunder, Thomas E (DDA) From: Galiunas, Elizabeth C [Elizabeth.C:Galiunas@conocophillips.com] Sent: Tuesday, August 26, 2008 4:06 PM To: Maunder, Thomas E (DOA); Alvord, Chip; Chambers, Mark A; Noet, Brian Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: CD2-470 Operations: Surtace Hole Issues Tom, ~'~ " ~'~ ~~~~-~. !looked with our production folks at OA pressures on CD2-54 (477' from CD2-75`s surface casing paint) and CD2-56 (378' away). These are the two closest surface casings to the surface casing of CD2-75. The OA data is recorded daily by the field operator. These show no noticeable change from last Thursday through today on the OAs that would indicate any interaction with CD2-75's annular disposal operations. Let me know if you need any more information. ~, Thanks; Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441-4€371 From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Monday, August 25, 2008 3:49 PM To: Galiunas, Elizabeth C; Alvord, Chip; Chambers, Mark A; Noel, Brian Cc; Regg, James B (DOA}; Davies, Stephen F (DOA) Subject: RE: CD2-470 Operations: Surface Hole Issues Liz, Thanks for the information. Interesting that the shoe of CD2-75 is over 850' from CD2-470. At lunch you mentioned that the wells might have been in the plain of minimum horizontal stress. Do 1 have that correct? Was pressure seen on any of the other wells proximate to CD2-75? Are there any other surface bbls that lie in the minimal horizontal stress plain? I look forward #o your reply. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] yen#: Monday, August 25, 2008 3:37 PM To; Maunder, Thomas E {DOA); Alvord, Chip; Chambers, Mark A; Noel, Brian Subject: CD2-470 Operations: Surface Hoie Issues Hi, Tom, On August 24th at 15:15 hrs, surface TD was reached on CD2-470 with a mud weight of 9.9 ppg. The rig began a wiper trip checking connections for flow. The connections up to stand 17 (204T MD}were static. At stand 17, slight flow was observed. The well was monitored for 10 minutes with slight flow continuing. The mud weight in and out at this point was 9.7 ppg. The mud weight was increase to 10ppg with slight flow. There_was no as cut mud. or other. hydn3carbons in t_h_e_mud_retums. The BHA was run back to bottom where the mud weight was increased#o a 10.2 ppg. 9/8/2008 • ~ Page 2 of 2 On Sunday, CD2-75 (308-213) was used for annular disposal for the first time with class 2 fluids from CD2- 470. CD2-470's TD is 867ft away from the surface shoe of CD2-75 (see attachment for details). I have also attached a detailed summary of all the injections on CD2-75. It was suspected that annular disposal on CD2-75 communicating with CD2-470. The decision was made to bleed off the annulus on CD2-75 back to a tiger tank. Initially the pressure was 1100 psi on the annulus. A total of 64 bbls of diesel and 9 bbls of water were bleed back on CD2-75's. Meanwhile, the gain rate on CD2-470 decreased and reached static. This morning, CD2-470 was monitored from 0400 - 0530hrs with no gain while circulating at 6 bph. The pumps were shutoff and the well was static for over 20 min. The rig began to pump out at this point monitoring each connection for flow. At around 8 AM, the decision was made to bull head diesel freeze protect on CD2-75 with 8 stands off bottom on CD2-470. While monitoring CD2-470, 54 bbls of diesel was pumped down the annulus on CD2-75. CD2-470 remained static through the pumping operations. Currently the pumping is complete down the annulus on CD2-75 and CD2-470 is still static. Once the rig was confident there was no flow from CD2-75, the rig began to pump out of the hole. Currently we are still coming out of the hole and is planning to rig up to run surface casing and cement operations once out of the hole. Since it appears CD2-75 is in communication with CD2-470, annular disposal operations on CD2-75 will be suspended indefinitely and CD1-19a will be utilized for disposal. Attached is the current rig surveys, CD2-75 injection summary, the Well View daily operations report up to midnight on 8/24/08, and details on surface shoe distances. Please call with any comments or questions. We will keep the AOGCC informed of any findings, like the Surface LOT and Annular test on CD2-470. Regards, Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441-4871 9/8/2008 CD2-75 Summary of Daily Annular Injection Volumes Origin of Fluids Start Time Stop Time Pump Rate Static Pressure Injection Pressure Mud Water for overflushing well Diesel for Freeze protecting Total Cummulative Weight Volume (ppg) Funnel Viscoity Comments Mud 5118/08 16:19 5/18/08 16:41 0.8 0 800 17 1 i Water 5/18108 16:52 5/18/08 18:05 4.2 740 1100 300 317 8.4 Flush annulus ost cement ob on intermediate Diesel 5/18/08 18:05 5/18/08 18:31 2.5 916 915 63 380 6.8 27 Freeze Protect Diesel 5/20/08 14:45 5/20/2008 1500 0.8 500 1050 10 390 6.8 27 Annular LOT Diesel 8/22/08 20:15 8/22/08 20:20 2 750 1320 10 400 6.8 24 In ectivit Test Diesel 8/24/08 9:36 8/24/08 9:39 2 930 120 5 405 6.8 24 In ectivit Test CD2-470 8/24/08 10:40 8/24/08 18:00 2 930 760 938 1343 10.1 70 Water Based Mud CD2-470 8/24/08 18:01 8/24/08 20:34 2 560 700 308 1651 9.8 70 WBM Water 8/24/08 20:35 8/24/08 21:13 3.8 690 900 120 1771 8.3. 27 Flush annulus Diesel 8/24/08 21:14 8/24/08 21:52 2 810 910 64 1835 6.8 24 Freeze Protect Diesel 8/25/08 8:40 8/24/08 18:00 2 520 1050 54 1889 6.8 24 Freeze Protect volume that was bleed off Total Volume 1888 bbls As or 1400 hrs 8126108 • • i • SURFACE CASING SHOE SEPARATION FROM CD2-75 CD2-75 X Y Surface Casing Shce ASP 4 Coordinates: 369536.58 5973218. ells Details ~ AOGCC ermit # ermit Date ource well Ann. VoI. "" tart Date nd Date is nce from Object well" Surface csg. Shce X Coord. Surface csg. Shce Y Coord. CD2-01 4544 373114.47 5976019.06 CD2-02 2903 36943133 5976119.22 CD2-03 3606 371040.60 5976495.42 CD2-05 0 888 370258.60 5973735.40 CD2-06 NA 0 3485 371610.81 5976018.45 CD2-07 NA 0 4076 372218.06 5976287.95 CD2-08 3927 372655.88 5975603.76 CD2-09 304-362 9/30/2004 418 3120 370318.00 5976239.00 CD2-10 304-289 7/30/2004 CD2-09, CD2-56 30703 8127/2004 10/15/2004 3591 371800.58 5976006.36 CD2-11 2557 370835.25 5975420.76 CD2-12 303-365 12/1212003 CD2-57,CD2-31 32000 5/15/2004 6/14/2004 2705 371071.29 5975445.60 CD2-13 4042 372658.78 5975785.31 CD2-14 301-288 10/9!2001 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 3185 372202.47 5974960.87 CD2-15 301-308 11/6/2001 CD2-50, CD2-25, CD2-04 31652 3/6/2002 9/21/2002 2190 370832.00 5974984.02 CD2-16 3319 372460 34 5974790.01 CD2-17 302-122 4!1012002 CD~B, CD2-08 18181 5129/2002 2/7/2003 2653 371774.00 5974645.00 CD2-18 1525 369825.76 5974716.05 CD2-19 303-083 4/2812003 CD2-58, CD2-52 31337 5119/2003 6/27/2003 3113 372284.88 5974681.33 CD2-20 304-288 7/30/2004 452 2930 371366.14 5975507.11 CD2-21 2176 370286.77 5975261.48 CD2-22 302-274 9120!2002 CD2-08, CD2-36, CD2-51 31253 217/2003 3/16/2003 2529 371678.61 5974562.30 CD2-23 303-080 4/28/2003 CD2-18, CD2-55, CD2-06 32000 914/2003 1/1/2004 2369 371013.17 5975070.46 CD2-24 301-186 7/13/2001 CD2-33 (+A&B), CD2-39, CD2-14, CD2-15 33995 7/16/2001 101912001 1859 370630.11 5974721.81 CD2-25 NA 2413 371594.00 5974479.00 CD2-26 302-068 314/2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/1712002 2627 371798.52 5974554.55 CD2-27 304-226 6/23/200 CD2-53, CD2-05, CD2-09 32000 7/9/2004 8/27/2004 3513 373046.07 5973071.83 CD2-28 3010 372139.80 5974728.95 CD2-29 303-249 8/2512003 CD2-06, CD2-30, CD2-27 29036 10/8/2003 11/19/2003 3539 372652.44 5974896.02 CD2-30 NA 0 1016 370473.52 5973610.96 CD2-31 NA 0 1266 369824.37 5974451.30 CD2-32 302-119 4/3012002 CD2-19,CD2-41, CD2-23 31113 6114/2002 7/23/2002 2066 371295.61 5974302.38 CD2-33 8"` 911 370155.64 5973886.23 CD2-34 302-069 314/2002 CD2-13, CD2-37 22842 10117/2002 11/2812002 2575 371803.06 5974439,79 CD2-35" 2888 372312.31 5974017.68 CD2-36 303-365 12/12/2003 CD2-03, CD2-31, CD2-57 32000 12/31/2003 719/2004 2333 371848.22 5973535.38 CD2-37 2062 371569.79 5972874.47 CD2-38 303-082 4!2812003 CD2~0, CD2-30 30011 7/28/2003 9/4/2003 2516 372033.86 5973527.13 CD2-39 301-281 10/9!2001 CD2-15, CD2~7, DD2-04 29945 10/10/2001 9/16/2002 2844 372350.61 5973633.17 CD2-40 NA 0 1294 370691.67 5973801.44 CD2404 307-154 518/2007 CD2-72 6764 5/14/2007 5/31/2007 2221 370646.55 5975142.76 CD2~1 303-081 4!28/2003 CD2-20, CD2-55,CD2-03 32000 6/2712003 7/28/2003 2523 371990.58 5973802.52 CD2~2 301-140 6!1!2001 CD2-24, CD2-33, CD2-33A, CD2-15 33992 6/1/2001 10/10/2001 1743 371098.46 5973992.48 CD2-43 Arctic asked 862 370344.04 5973520.68 CD2-04 2733 372034.57 5974328.53 CD2-45 301-345 12/1312001 CD2-09,CD2-17 22991 1/20/2002 2/1912002 3290 372765.13 5973853.74 CD2-06 302-273 9120/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 2419 371694.80 5974310.85 CD2~7 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 1697 371231.72 5973294.19 CD2~8 CD2-49 302-275 302-070 9!2012002 3!4!2002 CD2-28, CD2-35a, CD2-45, CD2-08 CD2-50, CD2-06, CD2-22 32000 27960 12/10/2002 4/22/2002 2/4/2003 5/28/2002 2158 1914 371631.74 371252.38 5973736.14 5974065.93 CD2-50 302-121 4/30/2002 CD2~1, CD2-19, CD2-16, CD2-38 32000 7/24/2002 9/7/2002 2356 371665.21 5974227.65 CD2-51 303-312 10128/2003 CD2-07,CD2-10 31769 11/19/2003 12124/2003 3583 373114.02 5973411.81 CD2-52 NA 3133 372637.61 5973661.63 CD2-53 304361 9/30/2004 CD2-56, CD2-54, CD2-02 26072 10/3/2004 8/5/2005 3434 372896.67 5972509.19 CD2-54 NA 0 477 369991.09 5973363.59 CD2-55 1582 371118.23 5973194.84 CD2-56 305-307 10111/2005 CD2~404 11167 5/7/2006 5/23/2006 378 369875.93 5973053.08 CD2-57 305-238 6/1712005 CD2-01 19181 8/22/2005 9/1212005 3131 372537.05 5972324.37 CD2-58 NA 2626 372102.03 5972657.80 CD2-59 839 369650.94 5974049.86 CD2-60 1945 371269.33 5972336.05 CD2-72 308-153 4/28/2008 CD2-75, CD2-064, CD2- 466, CD2-0G3 26564 5/3/2008 7/612008 1895 369745.64 5975101.63 CD2-75 308-213 7/8/2008 1420 8/23/2008 8/25/2008 0 369536.58 5973218.56 CD2-064 308-234 7/3/2008 C02-063, CD2~67 11759 7/6/2008 812312008 2517 372010.96 5973679.52 CD2-463 n 2997 372243.59 5974504.86 CD2-466 4072 370684.18 5977125.90 CD2~70 867 369030.33 5973922.14 CD2-467 y 1365 370335.86 5974325.43 "Lateral distance in feet, between surface casing shoes, in the X-Y plane "'CD2-35 was drilled from an ice pad in early 1998. The 9-518" x 7" annulus has not been permitted for annular disposal. ""CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' ND), shoe depth shown indicates window depth. It has not permitted for annular disposal. "" As of 8/25/2008 Note that this sheet is not the definitive record. _ • • -~ ~ Security Level: Development ~ ~~~Y.° ~~ r C Daily Drilling Report ,' ? i g ~~ ` {~ - CD2-470 ~' ~ -. Report Number: 4 . . • - Report Date: 8/24/2008 Rtg. DOYON 19 AFE Type Network/ID.it Total AFE+Sup . 9,505,997.00 Wellbore Well Type 10230102 Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-470 Development QANNIK 2.24 4.0 0.00 2,523.0 2,523.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 94 731,836.12 191 194 . , 19,085.94 62,573.12 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 6/21/2008 8/22/2008 28.43 28.22 0.21 9/19/2008 00:10 last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) 653.00 3 Conductor, 114.OftK6 , 10 3/4 Ops and Depth @ Morning Report 24hr Forecast Bleed OA PRessure f/ CD2-75; Circ & Cond MW to 10.2 PPG; Circ On Bottom /Bleeding OA of CD2-75 Circulate on Bottom Until Gains Stop; Complete Wiper Trip; POOH Last 24hr Summary Directionally Drilled 131/2" hole f/ 2523' - 3658' MD (TD) - 2390' TVD; Circulated & Conditioned Mud for Back Ream; OWFF (Static); Pump Out-of-Hole f/ 3658' - 204T MD; OWFF (Flowing); Monitored Well f/ 10 minutesand Flow Remained Constant; MW InlOut 9.7 PPG; Circulated Bottoms Up & Maintained ); Circulate & Condition MW to 10.0 PPG In/Out -Well Still Flowing; tions (Flowin ki C h ' ' g onnec ng ec MD C - 3658 10.0 PPG MW in; No Gas Cut Mud; RIH f/ 2238 No Eveidence of Gas /Oil Influx on Any Bottoms Up; Suspect PRessure Coming f/ CD2-75 -instructed Ball Mill to Stop Annular Injection of Mud, flush & Freeze Protect Well; Ball Miil Complete @ 2200; Shut Down to Monitor Well -Initially Flowed Back at 33.6 BPH then Dropped and Stabilized at 17 BPH General Remarks Weather Head Count Overcast, Wind W @ 15 Mph, WC 33 47.0 41 Deg No Accidents or Spiiis , TiNe , , Dave Burley, Rig Supervisor . ..: i Supeniisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Steve Shultz, Rig Engineer Rig Engineer Time.L Start -.- Time.- o ~ End .Tirrie Dur (brs} _ Phase Op Code QpSutrCode Time P-N-T TrD) Code Trbl Class. Depth Start, (ftKB) . 523 0 2 Deplh.End (ft1C8) 0 373 3 Ope2tion Directionally Drid 13 1/2" Hole f! 2523' - 00:00 12:00 12.00 SURFAC DRILL DDRL P . , . , 3373' MD 700 GPM @ 2550 Psi WOB 20 - 30 RPM 60 ADT = 8.86, AST = .75, ART = 8.11 P/U 149, S/O 116, Rot 129 12:00 15:15 3.25 SURFAC DRILL DDRL P 3,373.0 3,658.0 Directionally Drilled 13 1/2" Hole f/ 3373' - 3658' MD (TD); 2390' TVD 700 GPM @ 2600 Psi WOB 20 - 35 RPM 60 ADT = 2.62, AST = .14, ART = 2.48 P/U 149, S/O 119, Rot 132 15:15 16:15 1.00 SURFAC DRILL CIRC P 3,658.0 3,373.0 Circ Hole Clean Standing Back 1 Stand Every 30 Minutes f/ 3658' - 3373' MD; Flow Check Well (Static) 650 GPM @ 2250 Psi RPM = 60 16:15 19:30 3.25 SURFAC DRILL REAM P 3,373.0 2,047.0 Pump Out-of-Hale f/ 3373' - 2047' MD; 650 GPM @ 2150 Psi, 50 RPM, P/U 149, S/O 120, Rot 132; Fiow Check Every 5 Stands Latest BOP Test Data ,,.,.Date Comment. Page 1/3 tteporr rnu~au. yr c.a,awol _ _~„~ ~ Security Level: Development it ~~ ~- Daily Drilling Report ~r ~ CD2-470 ~' ~~ Report Number: 4 .. Report Date: 8124/2008 Rig: DOYON 19 Ttme:Lo _ Start End Dur Time - - Depth Start Deplh End . Time , 'Tune (his) Phase Dp Gode OpSub-Code P-NT Trbl Code TrbFClass. (~) (r1~) Operation 19:30 21:15 1.75 SURFAC DRILL TRIP T Well Control Swab / 2,047.0 3,658.0 Flow Check @ 2047' MD; Observed Surge slight flow - Monitired Weil 10 Minutes continued to observe slight flow; Mud Weight In/Out 9.7 PPG; Circulated down 2 stands to t/ 2238' MD; Circulate BU - maintain mud wt. in @ 10.0 ppg -mud wt out 9.7 - 9.8 ppg - no gas cut in mud - RIH f/ 2238' - 3567' MD -Checking Well On Connections -slight flow; Washed Down t/ 3658' MD -circulate and condition mud -maintain mud wt. in @ 10.0 ppg -mud wt. out 9.7 -10.0 ppg - no gas cut in mud - 21:15 22:45 1.50 SURFAC DRILL CIRC T Well Control Swab / 3,658.0 3,658.0 Circulate hole Staging Pumps Up f/ 450 Surge GPM - 600 GPM Cheking Mud Weight In/Out Every 5 Minutes circulate and condition mud -maintain mud wt. in @ 10.0 ppg -mud wt. out 9.7 - 10.0 ppg - no gas cut in mud -circulate until 10.0 PPG In/Out - 600 gpm / 1950 psi ! 50 rpm Suspect Pressure Coming from CD2-75; Instructed Ball Mill to Stop Injecting Mud, Flush & Freeze Protect Annulus 22:45 00:00 1.25 SURFAC DRILL OWFF T Well Control Swab / 3,658.0 3,658.0 Shut Down Pumps to Monitor Well; Well Surge initially Flowed at 33.6 BPH and Decreased to 17 BPH and Stabilized; Total gain +/- 25 Bbis with No gas or oil influx. Mud Check= Data YP Calc Gel (iDs) Gel (1Dm) Gel (30m) HTHP Filt Density Temp .Solids, Corr. TYPe DepthjflKB) Dens Qb/gal). :Vis.(slgt) 'PV Calc(cp). (Ihf/'IODFt?) pbff100fP) (lbfltODfi') (Ibf/1o0Ft') , ,MBT(Iblhbl) ,(m1.f30rnin) pH (°F) (~) Spud 3,658.0 10.00 284 49.0 69.000 43.0 89.0 117.000 5,257.6 9.0 9.0 Spud 3,658.0 9.85 284 42.0 70.000 46.0 73.0 110.000 5,257.6 9.0 8.5 Spud 3,268.0 9.80 284 36.0 72.000 49.0 86.0 116.000 4,819.5 9.0 8.0 Spud 2,674.0 9.40 284 12.0 67.000 42.0 64.0 76.000 4,819.5 8.8 6.0 In ection Flu id - Fluid Source From Lease (bbl) - - Destination _ Note. Diesel CD2-470 67.0 CD2-464 Diesel CD2-470 47.0 CD2-464 Diesel CD2-470 5.0 CD2-75 Diesel CD2-470 5.0 CD2-464 Drilling Mud WBM CD2-470 938.0 CD2-75 Drilling Mud WBM CD2-470 417.0 CD2-464 Drilling Mud WBM CD2-470 162.0 CD2-464 Drilling Mud WBM CD2-470 140.0 CD2-464 Water CD2-470 150.0 CD2-464 Water CD2-470 150.0 CD2-464 Water CD2-470 101.0 CD2-464 Water CD2-470 50.0 CD2-464 Page 2/3 Report Printed: 8/2512008 ~,r~ ~ Security Level: Development ~' I Daily Drilling Repo rt , - , ~ .,~, ~,~' R CD2-470 ~ _ ~ Report Number: 4 Rig: DOYON 19 Report Date: 812412008 Drill'Strin s:BHA`No. 1 - $teerable l'Bif.Ruri No. 1 - 13;712in Nu hes.Christen§en MXL>1 5149522 Depth In (ftfCB) Depth Out (ftKB) TFA (inci Noz) (ins) Nozzles (/32") IADC Bit Duli String Wt (10001bf) 114.0 2,523.0 0.75 12/16/18/16 59 Drill Strin Com onents '. Jls Item.Desatptton OD (ri) ID (in) ' °:" :Top Conn Sz (in)_ , Top Thread ~ '>;Cum Cen.(ft) _" Motor with Stabilizer B 5.000 6 5/8 H 90 31.96 Float Sub 7.92 2.875 6 518 H 90 34.35 Stabilizer 8 2.875 6 5/8 H 90 41.85 XO Sub 8.1 2.813 6 5/8 Reg 43.33 MWD (DM) 8 1.920 6 5/8 Reg 52.52 MWD (HCIM) B 1.920 6 5/8 Reg 61.61 MWD (TM) 8 1.920 6 5/8 H 9D 71.51 UBHO 8.03 2.875 6 5/8 H 90 74.41 NMDC 8 2.813 6 518 H 90 104.49 NMDC 8 2.813 6 5/8 H 90 135.46 Drilling Jars -Mechanical 7 1/4 2.750 4 1/2 IF 170.41 24 HWDP 5 3.000 4 1!2 IF 906.36 Weillio~es Wellbore Name Well6ore API/UWI CD2-470 501032058100 Section Size (in] Act Top (ftK6) Ad Blm (ItIC6) Stazl Date Ehd.Date COND1 24 0.0 114.0 2/22/2008 2!22/2008 SURFAC 13 1/2 114.0 3,653.0 8/22/2008 INTRMI 9 7/8 3,653.0 8,030.0 PROD1 6 3/4 7,880.0 16,717.0 Page 3/3 Report Printed: 8/25!2008 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 18, 2008 5:23 PM To: Maunder, Thomas E (DOA); 'Allsup-Drake, Sharon K' Cc: 'Noel, Brian' Subject: RE: CD2-75 (208-064) completion report correction Sharon and Brian, I made the corrections. Steve Davies had already corrected the rkb and gl elevations. Nothing further is needed. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, August 18, 2008 4:02 PM To: 'Allsup-Drake, Sharon K' Cc: Noel, Brian Subject: RE: CD2-75 completion report correction Page 1 of 1 Sharon and Brian, Let me have a look at the 407. I think I can make the corrections by hand. Just need to put may hands on the report. Tom From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Monday, August 18, 2008 4:01 PM To: Maunder, Thomas E (DOA) Cc: Noel, Brian Subject: CD2-75 completian report correction Tom - We have found an error on a completion report recently sent to AOGCC which we would like to correct. Should we send a corrected completion report or will this email satisfy in correcting this error. We would like to correct the PBTD and the RKB for well CD2-75. The completion report was sent on June 26, 2008. The PBTD should be corrected to 21198' MD / 7365' TVD. The RKB should be corrected to 52.3' and the GL should be corrected to 15.6'. Thank you, Sharon 263-4612 8/18/200$ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-064 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-75 2. Address: 4b. Well Status: Oil ^~ Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20573-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 308-213 7/8/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 390* 390 totals (bbls): 2008 / 3rd 2008 / 4th 2009/1st 2009 / 2nd Total Ending Report is due on the 20th 390 390 0 (bbls)e of the month following the final month of the quarter. Ex: Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-off test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~l -a ~O ~ Si '~ ~ "'--'"'"~ gnature: , Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 08, 2008 10:38 AM To: 'Reilly, Patrick J' Cc: Galiunas, Elizabeth C; Noel, Brian Subject: RE: CD2-75 2~8-064) -AGAIN ~-- Thanks much Pat. I knew what was submitted couldn't be for the surface. From: Reilly, Patrick J [mailto:Patrick.J.Reilly@conocophillips.com] Sent: Tuesday, July 08, 2008 10:36 AM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C; Noel, Brian Subject: RE: CD2-75 (208-064) -AGAIN Tom, Page 1 of~' ~. I am sorry about the mix up. The LOT sent in with the AD package was for the intermediate. The attached PDF has both the su ce and intermediate LOT's. Pat Reilly ConocoPhilfips Alaska Drilling 8~ Wells f A'~~ (~ (907) 265-6048 WORK 1 Y (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reil ly@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 08, 2008 9:21 AM To: Reilly, Patrick J Cc: Noel, Brian; Galiunas, Elizabeth C; Eggemeyer, Jerome C. Subject: RE: CD2-75 (208-064) -AGAIN Pat, I am continuing to look at this annular disposal application. Would you and your colleagues please have a look at the initial LOT for CD2-30 (10/23/03)? It appears that the depths of the 7" casing are used for determining the EMW rather than the depths of the 9-5/8". I wondered when the calculated EMW given was only 12.5. If the tvd of the 9-5/8" is used, the FIT value calculates to 20.0 EMW!! From the record, no application was ever made for CD2-30 and since the cementing/LOT information is only now being submitted, it is possible that this well was never within the'/4 mile radius of any other well considered for AD. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, July 08, 2008 8:43 AM To: 'Reilly, Patrick J' Cc: Noel, Brian; Galiunas, Elizabeth C Subject: RE: CD2-75 (208-064) 7/8/2008 . '~ Page 2 of Thanks Pat. This information answers my question. Tom From: Reilly, Patrick J [mailto:Patrick.J.Reilly@conocophillips.com] Sent: Monday, July 07, 2008 5:09 PM To: Maunder, Thomas E (DOA) Cc: Noel, Brian; Galiunas, Elizabeth C Subject: RE: CD2-75 (208-064) Tom, The LOT that was submitted with the AD permit application contained an error. The density of the annular fluid should be 7.26 ppg. EMW. That value assumes 6.8 ppg diesel down to 1667' TVD and water down to the shoe (2390 TVD). The attached PDF contains the following: 4 a es of o erations detail from Ma 18th - Ma 20tH ~ ~ C` ; The correct d annular LOT y y ~ ~`'~`` ~~~ ~ ~ C~ a .~~ 4 ~~~ ~~~ A full page PIT plot close up (The blue lines clearly indicate the two pressure trends) `~~~ The original annular LOT from May 19tH (The original test was repeated because the abrupt break over point and the large difference between break over pressure and shut in pressure caused us to suspect some type of plug was giving us an incorrect value. The first test indicated a 17.3 ppg LOT which was less than the original surface LOT of 17.8 pp9~) Please let me know if you need anymore information. Thanks. Pat Reilly ConocoPhillips Alaska Drilling 8~ Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 07, 2008 9:10 AM To: Reilly, Patrick J Subject: FW: CD2-75 (208-064) Here is that request. From: Maunder, Thomas E (DOA) Sent: Thursday, July 03, 2008 3:40 PM To: 'Chip Alvord'; 'Noel, Brian' Subject: CD2-75 (208-064) Chip and Brian, I am reviewing the application for AD for this well. On the pump-in, 6.9'ppg is "added" as the fluid weight to determine 15.3 EMW. There is a note at the bottom that says 1667' tvd is diesel and the remainder (723') is water. I haven't done the calculation but is 6.9 the appropriate "adder"? I haven't seen one of these where the column is a combination of diesel and water. Could you provide the report that details the pump-in? 7/8/2008 • Note to File CD2-75 (208-064...308-213) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 187 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 40% XS of the calculated hole volume. -- On the initial teak off test, the pressure rises relatively smoothly to 15.8 EMW. With additional pumping pressure continues to rise at a different slope to a maximum of 17.8 EMW. The pressure declined during the observation period to about 16.1 EMW. Two slopes are not unusual at Alpine. The initial leak off indicates that the surface casing shoe is well cemented. ----No problems are reported drilling the intermediate hole. The 7-5/8" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --Two infectivity tests down 10-3/4" x 7-5/8" annulus were conducted. On the initial test, the sharp pressure rise seems to indicate possible plugging in the casing x casing annulus. After the pressure break @ 17.3 EMW, the pressure declines to 14..6 EMW. Prior to conducting the 2"d test, the annulus was displaced with water and diesel. On the 2"d test, the pressure rises smoothly at a lower slope with pump in at between 15.6 - 15.5 EMW. During the observation period, the pressure declined to 14.8 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/. mile radius of CD2-75. The surface shoe of CD2-56 is 400' distant and the shoe of CD2-54 is ~ 475' distant. 4 wells are between 840' and 910' distant and 2 wells are over 1000' distant. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. G~~~,,,,,~ ~ Tom Maunder, PE Sr. Petroleum Engineer July 8, 2008 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\080708--CD2-75.doc i ~ Note to Fiie CRU CD2-75 (PTD 2080640) July 2, 2008 Re: ConocoPhillips' Application far Sundry Approval for Annular Disposal of DriWng Wastes within Well CD2-75 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus surrounding the T' casing within well CD2-75. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at about 3,340' measured depth (-2,338' true vertical depth subsea, or "TVDSS"), near the base of a 400-foot thick shale and mudstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone, sandy siltstone, and sandstone open to the surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. S. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 100' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Nuiqsut 1 and Alpine 1. The discussion that follows is based on well logs from Nuiqsut 1, Alpine 1, Colville River Unit (CRU) CD2- 55, CD 2-464, and CD2-39. Index maps are provided in Figures 1 and 2, below. The CD2-75 development well was drilled to the Qannik Oil Pool within the Colville River Unit. ConocoPhillips intends to dispose of drilling wastes utilizing an open annulus within CD2-75 that extends downward from the 9-5/8" surface casing shoe, which is set at about 3,340' measured depth (-2,338' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 13,300' measured depth (-6,640' TVDSS). This annulus lies within Sections 2, 3, 9 and I4 of T11N, R4E, UM (see Figures 1 and 2}, and it lies more than three miles from the current boundary of the CRU. The section of open annulus that will most likely accept the injected waste fluids is a portion of the Seabee formation that extends from 3,480' to 3,820' measured depth (-2,400' and -2,545' TVDSS; see Figure 3, below). This interval contains several 1- to 7-foot thick beds of siltstone, sandy siltstone and sandstone that are separated by mudstone and shale. The aggregate thickness of the siltstone, sandy siltstone and sandstone beds exposed to the wellbore is about 35'. The apparent siltstone that lies immediately beneath the 9-S/8" casing shoe of CD2-75 is likely an artifact caused by circulating and CD2-75 July 2, 2008 Note to File Page 2 of 6 cementing. In offset exploratory wells, the correlative sediments to those surrounding the 9-5/8" casing shoe consist of shale, claystone, and minor amounts of siltstone (see Figure 4, below). The 9-5/8" surface casing shoe lies near the base of a 400-foot thick interval that is dominated by shale and mudstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely injection interval is a 50-foot thick zone of claystone and mudstone that is also continuous throughout the area. This interval, which lies between 3,880' and 3,985' measured depth (-2,570' and -2,615' TVDSS), and several similar underlying strata will provide lower confinement for injected wastes. Figure 1. Indez Map (The path of the cross-section shown on Figure 3 is highlighted with magenta) In vicinity of Drill Site CD2, the base of permafrost occurs at about -1,200' TVDSS, which is about 1,100' shallower than the top of the proposed injection interval. Conclusion 3 of Area Injection Order 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Alpine 1 is an exploratory well located about two miles east of Drill Site CD2. In Alpine 1, methane was first encountered at 760' measured depth (about -720' TVDSS), and it was encountered in significant quantities (more than 1% methane in air, or SO units) at 1,155' measured depth (about -1,015' TVDSS). In Nuiqsut 1, located about 2-1/2 miles west of CD2-75, methane gas was first encountered at 710' measured depth (-653' TVDSS). So, the entire proposed disposal zone likely contains some methane gas. CD2-75 Note to File July 2, 2008 Page 3 of 6 -- ~ - \ _~~ ~~ c n5 ~ ~.~ ~ ~~-_z '\ ~~ .F nA ~ CD . -~-- 32 ` x.3,33 4 `Zz ~~' C 'SD CD 33B CD2-75 A~P, 2;, ~ C )5 ~ ~ ~ i ~" ~ __ ~ i ~~~F _ ~ - _ ~~. - 1 `~ ~ ~ , ~s ,~ ~' , z.5, Nuiqsut 1 ~ '~~ `° CD ~ ~ '~,~ Alpine 1 1 ~ ~ ~,, CRU CD2-75 8 I ,' Annulus ~~~ ~ ~a ~ ~ X30 _3~ ~, ~~ _- 4, \ ~1 t 19 ~ Figure 2. Expanded Index Map (CRU CD2-75 open annulus highlighted with red; the path of the cross-section shown on Figure 3 is highlighted with magenta) The shallowest oil show encountered in Alpine 1 was a poor show observed between 2,980' and 3,080' measured depth (from about -2,940' to -3,040' TVDSS). However, the description of this show note does not mention oil staining; the show was noted based on sample and solvent cut fluorescence. The shallowest record of visible oil staining is found in the description of a fair oil show that occurs from 4,025' to 4,080' measured depth (about -3,985' to -4,040 TVDSS), which is about 880 true vertical feet below the most likely receptor beds for the injected material. The shallowest oil show encountered in Nuiqsut 1 was a fair show observed between 3,990' and 4,070' measured depth (from about -3,930' to -4,010' TVDSS). The description of this show mentions free oil in the wet sample at 4,080' measured depth (-4,020' TVDSS). So, at Drill Site CD2, the most likely disposal interval does not contain potentially commercial hydrocarbons. The chart presented in Figure 5, below, provides an estimate of the subsurface volume around CD2-75 that will be affected by the proposed annular disposal operations. There are about 35' of porous siltstone, sandy siltstone and sandstone beds within the most likely disposal interval that are open to the wellbore, CD2-75 Note to File Upper Confining Strata Most Likely Receptor Strata for Disposed Fluids Lower Confining Strata Correlation Depth Ress GRi S:GR~= i <MD RT 1 i i api 240 .200 ohmm 200.000 and -Siff - hale TVDSS> T!%G ~MD Surface Casing ~ 2400 ~- 3400 _ y- '` •2400 t•i0 _~ ,.~ 3fjl_II_I ~ ~: ?,~I_II_I ~~i Ill 1 ~~ 3800 _y L t 1, LTV 3900 ` .~ ~., ._.. 4000 _ ' i .~ ~} ~ I_II_I . :^^~ f ,F July 2, 2008 Page 4 of 6 Figure 3. CD2-75 Well Log for Affected Intervals ~ r CD2-75 Note to File July 2, 2008 Page 5 of 6 ,980250 2080640 501032025300 11&13fl 50103205]300 404]11 w ARCO GONOGOPHILLIPS ALASK NUIOSUT 1 COLVILLE RIV UNIT C02-]5 2031180 501032096300 2609 CONOCOPHILLIP6 AlA5K COLVKLE RN UNIT GD255 3080820 fl 50103205)400 LONOCOPHILLIPS ALASK GOLVILLE RN UNR GD2-069 20i16W 1991]20 i85M 501032038)00 2339fl 501032021100 ~-1 CONOCOPHILLIPS ALASK ARGO Ly COLVILLE RN UNR CD2J9 ALPINE 1 14 - - __ _ - t s i' . soo -. ~ w° I -' i - -) ~. .~ r" .. 3. ~~ - _ - - - -10W - ~ ~ - I - - _ - - - - ' J -1aaD ~ ~_ - ___.. - - _ i - f ,. - ~ - - ~ i e .. I -~ ? -tsoo 1 I I _~ f r> 9-5/8" casing shoe 'I~ ! ~ -200D - . _ ~- _ Upper Co~ I nfi~ ning Strata - i ~ -2000 ~ i ' r- 1 -~ - ~ zDisposal Z 25~ one { _ 1 - 1 ~ -2500 x_ Lo~Ve ~- t ~, ~ r ~' t i; - - s ~ -- - _ ~ ~ Confini f ng - ~ - - 3 ~ - - I ~ ' aow Str t ~ ~ - f ~ ~ x } - 360D r a a '~ _ _ r -t - - # - ' }} 500 ~ - R _~ 3 .. ` _ ( ~. - ; - , 1 ~-~- _ - , i ; ~ { a5W . p . ~ ~ l . ;. . - _ t ~ _ . F4F { ~. 1 ~ ~ - 1 . 1 - ~- i 11 - $ { _ :._ s. ~ ~ ~ _ I i t ~ _ ! TD=13696 i f~ ` ~~ 1 -~ - ~ ~ 5 ~ ~ -4500 - ~ ~ r ~ ! ~ _ _ _ - ~ I ~ ~ _ - - ~ ~ .500 ~` Figure 4. Structural Cross-section from Nuiqsut 1 to Alpine 1 according to a count using the gamma ray curve from CD2-75. Porosity well logs were run across this interval in Alpine 1, CD2-32, and Nuiqsut 1, which are located 2 miles east, 1 mile east, and 2-1/2 miles west, respectively. Inspection of the density porosity measurements in offset wells Alpine 1 and Nuiqsut 1 suggests an average porosity of about 27% for the siltstone, sandy siltstone, and sandstone beds. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of less than 100' from the wellbore, as indicated below. i ~ CD2-75 Note to File Injected Fluid vs Affected Radial Distance CD2-75 Wellbore (assumes 35 injection zone thickness open to the weilbore and 27% porosity) 300 250 w d `o a 3 200 is 0 m ~ 150 a O W ~i5 100 eo v m ~ 50 Q 0 Figure 5. Radial Distance Potentially Impacted by CD2-75 Injection Summary July 2, 2008 Page 6 of 6 The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,100' of permafrost, and is bounded above and below by continuous layers of shale, mudstone and minor amounts of siltstone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath CD2-Pad. The open annulus that will be used for disposal injection lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I recommend ap royal of this annular disposal project. Steve Davies Senior Petroleum Geologist lO~~~l ~G ;% 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) COI~TSER~7I0 CO1~IIII SIp15~T Chip Alvord Alpine Drilling Team Lead ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD2-75 Sundry Number: 308-213 Dear Mr. Alvord: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production .casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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, Dan T. Seamount ~~ Chair DATED this day of July, 2008 • Encl. ~~~~~ ~ ~ ,s~ ~ ~ ~o~ ~~ Q~~ ~~ ,JUN 1 9 200$ (~Q~' U STATE OF ALASKA ~/ Alaska Oil & Gas Cons. C~#ib~± OIL AND GAS CONSERVATION COMMISSION An~1<oraga ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 1. Operator 3. Permit to Drill Name: 208-064 ` ConocoPhillips Alaska 4. API Number: 50-103-20573-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD2-75 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD2-5, CD2-31, CD2-33, CD2-40, CD2-43, CD2-54, CD2-56, Torok and Seabee formation, shale, siltstone and sandstone . CD2-59, CD2-30 ~~ R`S~Cc[-~~~ V\\~ ~~c`~'`~~r`~ b) Waste receiving zone: t b) water wells within one mile: W ~`~ ~ ~ `L ~ Sand layers below the C30 marker in the Seabee formation Y None ~(c6`~ c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2212 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- formation fluids associated with the diesel completion fluids contaminated drilling mud 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 30-Jun-OS added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drillin a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) Q Cement Bond Log (if required) ^ FIT Records w/LOT Graph Surt. Casing Cementing Data 0 Other ^~ previous authorization for new product cleanup fluids for CD1 and CD2 oregoing is true and correct to the best of my knowledge. 18. I hereby certify that the f ~~? ~ ~ 1 / Signature: ~•~ '~*- .. n Title: ~_~ ~'rl ~r~~C'eGv- ~ t1°', Printed Phone Name: Chip Alvord Number: 265-6120 6/18/2008 Commission Use Only , Conditions of approval: p~ ~~~p~S'~,r\GLLpc~ "'~~8-(~j ~r~S~G~~V LOT review and approval: , ~b Subsequent form required: `~'~~"~ Approval number. ~ ~ C1 - ~ ~ 3 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403RD Rev. 6/2004 ' ( S V~S~ ~ 1~0~ Sub it in Duplicate • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 18, 2008 Alaska Oil and Gas Conservation Commission 333 West 7t1i Avenue Suite 100 L` ConocoPhillips ~IUN 1 9 2008 Anchorage, Alaska 99501-3539 ~. Ct7t~s, COmrpis,-on Alaska Oil & G~~ Re: Application for Sundry Approval for Annular Disposal of DrillinE Waste on w`CD~~S Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-75 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The anticipated start date for annular disposal operations on CD2-75 is June 30, 2008. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on surface x intermediate casing annulus 11. Information regarding wells within '/4 mile radius at AOGCC: CD2-5, CD2-31, CD2-33, CD2-40, CD2-43, CD2-54, CD2-56, CD2-59 12. Information regarding remaining wells within'/4 mile radius included in sundry package: CD2-30 13. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial. annular LOT (15.3 ppg) occurred at a lower equivalent mud weight than the casing shoe test (17.8 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Pat Reilly at 265-6048; Chip Alvord can also be reached by calling 265-6120. Sincerely, ~~~~~ Pat Reilly cc: Drilling Engineer CD2-75 Well File Chip Alvord Sharon Allsup-Drake ATO-1577 ATO-1530 Annulus Disposal Transmittal Form -Well CDZ-75 AOGCC Reeulations. 20 AAC 25.080 (bl 1 Desi nation of the well or wells to receive drillin wastes: CD2-75 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2212 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD2-464, CD2-466, CD2-463, CD2-465, CD2-73, CD2-74 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi /Iaximum Fluid Density to avoid Burst of Surface Casinz? tburst85% - PHydrostalic +PApplied - PFotmation Version I 0 -Jen'Oi 3,043 = ( 2,390 * 0.052 *MWmax ) + 1500 - (0.4337 * 2,390 ) MWmax = 20.75551 ppg Surface Casine Strin Size 10.75 in Weight 45.5 ppf Grade L 80 Pburstl00% 3,580 psi Pburst85 % 3,043 psi Depth of Shoe 2,390 ft FIT/LOT @ Shoe 17.8 ppg or 2,212 psi FIT/I.OT for Annulus 15.3 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing Stringy - collapse85% - PHydros[atic +PApplied - PGasGradient - Header 4,072 =( 6,688 * 0.052 *MWmax )+ 1,500 - (0.0700 * 6,688) - 1,000 MWmax = 11.6157 ppg 2nd Casine Strin Size 7.625 in Weight 29.7 ppf Grade L 80 Pcoltapse100% 4,790 ps1 Pcollapse85% 4,072 psi Top of Cement 6,688 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casin:? Shoe P,naxallowable=Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,390 * .052 * 17.8 ) Pmax allowable - 2+212 pSl This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". Well CD2-75 Date 6/10/2008 SURFACE CASING SHOE SEPARATION FROM CD2-75 CD2-75 x Y Ci iAaro Caeinn Rhnc CCP d Rnnrriinatos~ 3RAF3R FA 5A7391 R 5R ells CD2-35** Details ~ AOGCC ermit # ermit Date ource well Ann. Vol. *""" tart Date nd Date istance from Object well* 2888 Surtace csg. Shoe X Coord. 372312.31 Surface csg. Shoe Y Coord. 5974017.68 CD2~2 301-140 6/1/2001 CD2-24, CD2-33, CD2-33A, CD2-15 33992 6/1/2001 10/10/2001 1743 371098.46 5973992.48 CD2-24 301-186 7/13/2001 CD2-33 (+A&B), CD2-39, CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1859 370630.11 5974721.81 CD2-33 B*** 910 370155.64 5973886.23 CD2-39 301-281 10/9/2001 CD2-15, CD2~7, CD2-44 29945 10/10/2001 9/16/2002 2844 372350.61 5973633.17 CD2-14 301-288 10/9/2001 CD2~5, CD2~7, CD2-32 31073 11/13/2001 3/5/2002 3185 372202.47 5974960.87 CD2-15 301-308 11/6/2001 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 2190 370832.00 5974984.02 CD2~7 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 1697 371231.72 5973294.19 CD2~5 301-345 12/13/2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 3290 372765.13 5973853.74 CD2-34 302-069 3/4/2002 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 2575 371803.06 5974439.79 CD2-26 302-068 3/4/2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 2627 371798.52 5974554.55 CD2-49 302-070 3/4/2002 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 1914 371252.38 5974065.93 CD2-17 302-122 4/10/2002 CD-48, CD2-08 18181 5/29/2002 2/7/2003 2653 371774.00 5974645.00 CD2-32 302-119 4/30/2002 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 2066 371295.61 5974302.38 CD2-50 302-121 4/30/2002 CD2-41, CD2-19, CD2-16, CD2-38 32000 7/24/2002 9/7/2002 2356 371665.21 5974227.65 CD2-25 NA 2413 371594.00 5974479.00 CD2~6 302-273 9/20/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 2419 371694.80 5974310.85 CD2-22 302-274 9/20/2002 CD2-08, CD2-36, CD2-51 31253 2/7/2003 3/16/2003 2529 371678.61 5974562.30 CD2~8 302-275 9/20/2002 CD2-28, CD2-35a, CD2 45, CD2-08 32000 12/10/2002 2/4/2003 2158 371631.74 5973736.14 CD2-19 303-083 4!28/2003 CD2-58, CD2-52 31337 5/19/2003 6/27/2003 3113 372284.88 5974681.33 CD2-41 303-081 4/28/2003 CD2-20, CD2-55,CD2-43 32000 6/27/2003 7/28/2003 2523 371990.58 5973802.52 CD2-23 303-080 4/28/2003 CD2-18, CD2-55, CD2-06 32000 9/4/2003 1/1/2004 2369 371013.17 5975070.46 CD2-16 3319 372460.34 5974790.01 CD2-38 303-082 4/28/2003 CD2-40, CD2-30 30011 7/28/2003 9/4/2003 2516 372033.86 5973527.13 CD2~4 2733 372034.57 5974328.53 CD2-29 303-249 8/25/2003 CD2-06, CD2-30, CD2-27 29036 10/8/2003 11/19/2003 3539 372652.44 5974896.02 CD2-13 4042 372658.78 5975785.31 CD2-37 2062 371569.79 5972874.47 CD2-28 3010 372139.80 5974728.95 CD2-08 3927 372655.88 5975603.76 CD2-36 303-365 12/12/2003 CD2 13, CD2-31, CD2-57 32000 12/31/2003 7/9/2004 2333 371848.22 5973535.38 CD2-51 303-312 10/28/2003 CD2-07, CD2-10 31769 11/19/2003 12/24/2003 3583 373114.02 5973411.81 CD2-12 303-365 12/12/2003 CD2-57, CD2-31 32000 5/15/2004 6/14/2004 2705 371071.29 5975445.60 CD2-58 NA 2626 372102.03 5972657.80 CD2-52 CD2-20 304-288 7/30/2004 NA 452 3133 2930 372637.61 371366.14 5973661.63 5975507.11 CD2-55 1582 371118.23 5973194.84 CD2-40 NA 0 -~ 1294 370691.67 5973801.44 CD2-30 inGuded NA 0 1016 370473.52 5973610.96 CD2-18 1525 369825.76 5974716.05 CD2-06 NA 0 3485 371610.81 5976018.45 CD2-27 304-226 6/2312004 CD2-53, CD2-05, CD2-09 32000 7/9/2004 8/27/2004 3513 373046.07 5973071.83 CD2-10 304-289 7/30/2004 CD2-09, CD2-56 30703 8/27/2004 10/15/2004 3591 371800.58 5976006.36 CD2-07 NA 0 4076 372218.06 5976287.95 CD2~3 862 370344.04 5973520.68 CD2-57 305-238 8/17/2005 CD2-01 19181 8/22/2005 9/12/2005 3131 372537.05 5972324.37 CD2-31 NA 0 1266 369824.37 5974451.30 CD2-53 304-361 9/30/2004 CD2-56, CD2-54, CD2-02 26072 10/3/2004 8/5/2005 3434 372896.67 5972509.19 CD2-05 0 888 370258.60 5973735.40 CD2-09 304-362 9/30/2004 418 3120 370318.00 5976239.00 CD2-56 305-307 10/11/2005 CD2-404 11167 5/7/2006 5/23/2006 -~ 378 369875.93 5973053.08 CD2-54 NA 0 477 369991.09 5973363.59 CD2-21 2176 370286.77 5975261.48 CD2-59 839 369650.94 5974049.86 CD2-60 1945 371269.33 5972336.05 CD2-03 3606 371040.60 5976495.42 CD2-02 2903 369431.33 5976119.22 CD2-Ot 4544 373114.47 5976019.06 CD2-11 2557 370835.25 5975420.76 CD2-72 308 4/28/2008 CD2-75 399 1895 369745.64 5975101.63 CD2-404 y 307-154 5/8/2007 CD2-72 6764 5/14/2007 5/31/2007 2221 370646.55 5975142.76 CD2-75 inGuded 0 369536.59 5973218.56 * Lateral distance in feet, between surtace casing shoes, in the X-Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been perritted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. *** As of 5/31 /2007 Note that this sheet is not the definitive record. I COnOGOPfII~II~?5 ~\ \~ n -550 0~.; Calculation Methotl: Mlnlmum CurvaNre Error syatem: IscwsA 8wn Method: Trav. Cylintler NorN Error surface: Elliptical Coni< Warning Method: Rules eased Geotle0c Datum: North American DaNm 7983 Magnetl<MOtlel: BGGM2007 Ground Level: 15.60 RK6: CD2-75 Rig @ 52.30ft ~DOyon 19 (75.6 + 36.7J) Northing/ASP Y: 5973697.83 Fasting/ASP X: 1517223.26 ti G°23 O z 1100 0 -1650- , ~o a w p,0 G° . 00- DeJ _ h~ G~~~ ,' Project: Western North Slope Site: CD2 Alpine Pad Well: CD2-75 TDed Wellbore: CD2-75 TDed CD2-75 TDed coz;yy ~°~2A SurfCsg CD2-75 TDed Quarter Mile View m ~, G°za N i ~o' 4400 ~°ti5°= 0 ~ =33 ~ oy-2750 -2200 -1650 -1100 ' yy 2~~ p2'A'~ °tiyb ry"p2 C°~" COQ, 9 ~ O ~° West(-)/East(+) (550 ftlin) / _c~7: _c~'Y _ _ , G°~~~ O _ _ _ _ _ G°~60 a$ G°2 COI'lOCO~'tl~~l S p Casing Detail 10 3/4" Surface Casing Well: CD2-75 Date: 5/8/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.02 FMC Gen V Hanger 2.14 36.02 Jts 3 to 82 80 Jts 10-3/4" 45.5# L-80 MBTC Csg 3229.93 38.16 Halliburton Float Collar 1.21 3268.09 Jts 1 to 2 2 Jts 10-3/4" 45.5# L-80 MBTC Csg 82.59 3269.30 Weatherford Float Shoe 1.72 3351.89 3353.61 TD 13 1/2" Surface Hole 3363.00 13-1 /2" Hole @ 3363' MD / 2394.2' TVD 10-3/4" Shoe @ 3353.61 ' MD / 2390.1' TVD RUN TOTAL 47 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #14 (stop ring on Jt #1 & 2 ) and over collars on jts # 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64,66,68,70,72,74,76,78, 8~ 80 90 joints in the pipe shed. Run 82 joints Last 8 joints stay out Use Best-o-Life 2000 i e do e All joints drifted 9.875" MU torque ~ 9500 ft/Ibs Remarks: PUW - 200K SOW - 135K Block Wt - 75k Supervisor.' D. Burley / L. Hill • p ~ ~~` Cement Detail Report CD2-75 ... °- Surtace Casing Cement Page 1/1 Report Printed: 6/12/2008 Cement Details Description Cementing Start Date Cementing End Date _ Wellbore Name Surtace Casing Cement 5/9/2008 04:02 5/9/2008 06:20 CD2-75 Comment __ - - Cement Stages.. _ ___ _ - - ___ _-- Stage # <Stage Number?> Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Surtace Casing Cement 0.0 3,354.0 Yes 187.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 600.0 1,200.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.9 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/ nut plug marker - Switch over to Dowell -Pumped 3 bbls of FW -tested lines to 3100 psi -pumped 12 bbls FW- Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 5.8 BPM @ 155 psi -Mixed & pumped 433 bbls 10.7 ppg Lead slurry (ASL) @ 7.2 BPM / 182 - 210 psi -Observed nut plug marker @ shakers w/ 418 bbls lead slurry pumped - (pumped down surge can 433 bbls total) Switched to tail slurry -Mixed & pumped 61 bbls 15.8 ppg lead slurry (Class G w/ adds @ 5.3 BPM @ 155 psi -Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cement w/ 292.7 bbls 9.9 ppg mud @ 7 BPM / 330 to 750 psi slowed pump to 4.2 BPM / 600 psi (for the last 6 bbls of displacement) Bumped plug to 1200 psi -Check floats OK - CIP @ 0620 hrs. - Full circulation throughout job w/ 187 bbls 10.7 ppg cement returns to surtace -reciprocated pipe while cementing and first 70 bbls of mud displacement -hole getting sticky -lost 32K SOW -landed casing for remainder ofjob Cement Fluids 8~ Additives - - --_ -- --- Fluid __ - Fluid T - _- ype Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 2,854.0 525 G 433.0 Yield (fN/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.63 21.75 10.70 Additives Additive Type Concentration Conc Unit label Fluid _ - - --- Fluid Type Fluid Description E stimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,854.0 3,354.0 280 G 61.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label J Security Level: ~'~ ~ ` ~~ Daily Drilling Report % h " ~~4, ~ CD2-75 ... . Report Number: 6 Rig: DOYON 19 Report Date: 5/9/2008 AFE Type Network/1D # Total AFE+Sup - Drilling 10218060 11,248,054.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-75 Development ALPINE 3.53 6.0 0.00 3,363.0 3,363.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,119.17 62,146.62 561,858.17 1,452,716.62 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/4/2008 5/6/2008 36.98 34.48 2.50 6/8/2008 03:07 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 3,353.6ftK6 Ops and Depth @ Morning Report 24hr Forecast Picking up BHA. Make up BHA and RIH Cleanout shoetrack. Drill 20'. FIT. Change mud and drill. Last 24hr Summary Ran and landed casing to 3,353'. Circulated. Cemented casing. Tested casing to 3000 psi for 30 min. OK. Set test plug and tested BOP. Tested Pipe Rams, Blind Rams, Chokeline and Manifold to 250/3500 psi. Tested Annulur to 250/2500 psi. Tested closing unit. Al l equipment test good. Witiness of test waived by Bob Noble of AOGCC. Set wear bushing and picked up DP standing it back in the derrick. General Remarks Weather Head Count Cloudy 47.0 _ Supervisor - Title Dave Burley, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor 'Time Lo - -- _ _ __ Start End Dur Time ~ 1 Depth Start _ __ _ _. Depth End Tlme Tlme (hrs) Phase ', Op Code OpSub Code P N-T Trbl Code Trbl Class- ~ (ftKB) (ftKB) Operation 00:00 01:15 1.25 SURFAC CASING RNCS P ~ 2,425.0 3,353.0 RIH with 103/4" 45.5# L-80 BTCM casing from 2425' to 3310' (82 jts total) - MU FMC fluted mandrel hanger and LJ - Land casing with shoe @ 3353.61' & FC @ 3268.09' 01:15 01:45 0.50 SURFAC CEMENT RURD P 3,353.0 3,353.0 RD casing slips and tongs - LD fill up tool - blow down top drive - RU cement head and lines 01:45 03:45 2.00 SURFAC CEMENT CIRC P 3,353.0 3,353.0 Circulate and condition mud for cementing - 7 bpm / 400 psi - reciprocated pipe with full returns throughout - PJSM -Line up to cementers Latest BOP Test Data _- Date..._ _..__1--...- ---.... Comment 5/9/2008 250/2500/3500 Page 1/3 Report Printed: 6/12/2008 • • Security Level: ~ ~ x ,t ~ , Daily Drilling Report , ~ _ _ ._ , _ _~ ~ CD2-75 Report Number: 6 Rig: DOYON 19 Report Date: 5/9/2008 Time Log _ Start End f Dur ___ Time i ! Depth Start ; Depth End Time Tlme 'I (hrs) ~ Phase Op Code OpSub-Code p-N-T ~ Trbl Code Trbl Ckass. (ftKB) (ftKB) Operation 03:45 06:45 3.00 SURFAC CEMENT DISP P 3,353.0 3,353.0 Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.9 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/nut plug marker - Switch over to Dowell -Pumped 3 bbls of FW -tested lines to 3100 psi -pumped 12 bbls FW- Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 5.8 BPM @ 155 psi -Mixed & pumped 433 bbls 10.7 ppg Lead slurry (ASL) @ 7.2 BPM / 182 - 210 psi - Observed nut plug marker @ shakers w/ 418 bbls lead slurry pumped - (pumped down surge can 433 bbls total) Switched to tail slurry -Mixed & pumped 61 bbls 15.8 ppg lead slurry (Class G w/ adds 5.3 BPM @ 155 psi -Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 292.7 bbls 9.9 ppg mud @ 7 BPM / 330 to 750 psi slowed pump to 4.2 BPM / 600 psi (for the last 6 bbls of displacement) Bumped plug to 1200 psi - Check floats OK - CIP @ 0620 hrs. -Full circulation throughout job w/ 187 bbls 10.7 ppg cement returns to surtace - reciprocated pipe while cementing and first 70 bbls of mud displacement -hole getting sticky -lost 32K SOW -landed casing for remainder of job 06:45 07:45 1.00 SURFAC CASING DHEQ P 3,353.0 3,353.0 RU and test 10 3/4" casing to 3000 psi for 30 minutes - RD & blow down lines 07:45 09:00 1.25 SURFAC CASING RURD P 0.0 0.0 LD -cement head & landing joint - RD casing elevators and bails - PU and spot GeoSpan skid onto rig floor 09:00 11:15 2.25 SURFAC CASING NUND P 0.0 0.0 PJSM - ND flowline - LD Riser -remove FMC speed head from conductor -Install FMC Unibody wellhead -test M/M seal to 1000 psi for 10 minutes 11:15 13:00 1.75 SURFAC WELCTL NUND P 0.0 0.0 NU BOPE stack -riser &flowline 13:00 18:00 5.00 SURFAC WELCTL BOPE P 0.0 0.0 Set test plug and tested BOP. Tested Pipe Rams, Blind Rams, Chokeline and Manifold to 250/3500 psi. Tested Annulur to 250/2500 psi. Tested closing unit. All equipment test good. Witiness of test waived by Bob Noble of AOGCC. Pulled test plug. 18:00 18:30 0.50 SURFAC DRILL OTHR P 0.0 0.0 Installed long wear bushing. 18:30 00:00 5.50 SURFAC DRILL PULD P 0.0 0.0 Picked up 5"drill pipe from pipeshed and stood back in the derrick. __ _ __ ____ MUd Check data _ _ ~~ YP Calc ~ _ ___ Gel (COs) Gel (10m~ l t Density Temp Sol;ds Corr I ype Depth (ftKB) i Dens Qblgal) Vs (s/qt) PV Calc (cp) (Ibf/100f[') ~ Qbf/100ft~) (Ibfl100ff~ bf/10Off~) I MBT Qb/bbl) j (mL 30mi p~ E I Spud Mud 3,363.0 9.80 43 17.0 15.000 6.0 19.0 22.000 25.0 9.3 9.5 Page 2/3 Report Printed: 6/12/2008 • Security Level: ' == Daily Drilling Report r~, ~ ~:; .: - CD2-75 , - .«. . Report Number: 6 Rig: DOYON 19 Report Date: 5/9/2008 __- - _ - ',Injection Fluid - Fluid Source From Lease (bbl) Destination Note 'Diesel 50.0 CD2-72 From CD2-75 Other 645.0 CD2-72 same Water 150.0 CD2-72 Same Water Based Mud 1318.0 CD2-72 same Drill Strings: BHA_N_o. 1 - 8" Mtr, 4/5, 5.3st /Bit Run No_. 1 - 13 1/tin, Hughes Christens_e_n , MXL-1 X, 5139593 _ Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dull String Wt (10001bf) 114.0 3,363.0 0.75 16/12/16/18 1-2-WT-G-F-2-HC-TD 45 Drill String Components - _ - -_ _ __ _ _ __ Jts Item Descri tion P OD in ID in To Conn ( ) _( ) _ P Sz in To Thread Cum Len ft ( ) P ( ) _-- Motorwith Stabilizer 8 4.947 7 5/8 H 90 32.25 Float Sub 7.92 3.000 6 5/8 H 90 34.65 Stabilizer 8.01 2.875 6 5/8 H 90 39.96 XO Sub 7.98 3.250 6 5/8 Reg 41.60 MWD (DM) 7.92 3.000 6 5/8 Reg 50.57 MWD (HCIM) 8 1.920 6 5/8 Reg 59.26 MWD (TM) 7.86 3.250 6 5/8 H 90 69.13 UBHO 7.88 3.500 6 5/8 H 90 72.03 NMDC 7.78 2.813 6 5/8 H 90 102.99 NMDC 8 2.813 6 5/8 H 90 134.00 Drilling Jars -Mechanical 7.35 2.750 4 1/2 IF 168.95 24 HWDP --_ _ _ __ 5 3.000 _ _ _ 41/2 IF 904.76 Wellbores __ Wellbore Name ~ Wellbore API/UWI CD2-75 I 501032057300 Section Size (in) ~i, Act Top (ftKB) Act Btm (ftKB) Start Date End Date COND1 36 36.0 114.0 2/20/2008 2/21/2008 SURFAC 131/2 114.0 3,363.0 5/6/2008 5/8/2008 INTRM1 9 7/8 3,363.0 15,717.0 5/10/2008 5/15/2008 PROD1 6 3/4 -- 15,717.0 23,539.0 5/22/2008 --- _ _ _ __ _ _ 5/27/2008 _ - Casing Strings _ Casin Description I Run Date ', OD Qn) 9 W[ QbsRt) i Grade Set Depth (ftKB) Comment _ Surface 15/9/2008 10 3/41 45.50 L-80 3,353.6 - - . Cement Surface Casin Cement -Started 5/9/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD2-75 Surface, 3,353.6ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) Surface Casing Cement 0.0 3,354.0 4 600.0 Fluid Class Amount (sacks) V (bbl) t Density Qb/gal) Yield (ft'/sack) Est Top (ftKB).__ .Est Btm (ftKB) Lead Cement G 525 433.0 10.70 4.63 36.0 2,854.0 Tail Cement G 280 61.0 15.80 1.17 2,854.0 3,354.0 Page 3/3 Report Printed: 6/12/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-75 Rig: Doyon 19 Date: 5/9/2008 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: D. Burley / L. Hill Pump used: #z Mud Pump ~ Strokes ~ 0.1000 Bbls/Strk ~ 7.0 Strk/min ~ Type of Test: Casing Shoe Test LOT/FIT ~ Pumping down annulus and DP. ~ Casin g Test Pressure In tegrity Test HOIe Slze: USE PICK LIST ~ Casing Shoe Depth Hole Depth Pum ping Shut-in Pumping Shut-in RKB-CHF: 36.0 Ft 3,354 Ft-MD 2,390 Ft-TV 3,383 Ft-MD 2,403 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: io-3/4" 45.5#/Ft L-80 BTC ~ 0 0 0 3070 0 0 0 1000 Casin Test Pressure Int e ri Tes 1 2 170 1 3070 1 30 0.25 990 Mud Weight: 9.9 ppg Mud Weight: 9.8 ppg 4 310 2 3060 2 80 0.5 970 Mud 10 min Gel: 25 0 Lb/100 Ft2 Mud 10 min Gel: 18.0 Lb/100 Ft2 6 480 3 3060 3 120 1 940 Test Pressure: . 000 3 psi Rotating Weight: 120,000 Lbs 8 650 4 3060 4 . 180 1.5 900 Rotating Weight: , 75 000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 810 5 3060 5 250 2 880 Blocks/Top Drive Weight: , 75 000 Lbs Desired PIT EMW: 18.0 ppg 12 960 6 3060 6 320 2.5 860 Estimates for Test: , 3.6 bbls Estimates for Test: 1019 psi 1.2 bbls 14 1050 7 3060 7 390 3 850 ~ ~ 16 1170 8 3050 8 460 3.5 830 EMW =Leak-off Pressure + Mud Weight = 1000 PIT 15 Second 18 1300 9 3050 9 520 4 820 + 9.8 0.052 x TVD 0.052 x 2390 Shut-in Pressure, psi 20 1440 10 3050 10 580 4.5 810 EMW at 3353.61 Ft-MD (2390.1 Ft-TVD) = 17.8 990 22 1570 15 3040 11 , / 640 5 800 v Lost 50 s i durin test held 24 1710 20 3030 12 ., 700 5.5 800 3500 p g , 4 F 98 % of t est pre ssure. 26 1860 25 3020 13 - 750 6 800 . , r - ' -- ' 28 2020 30 3020 14 '' 800 6 5 790 , ' '." ~~, _ 'ram„ . 3000 30 2170 15 840 7 790 . 2 20 16 880 7 5 790 32 3 - . ' 7 zsoo 34 2480 17 • 910 8 90 790 36 2630 18 940 8.5 ` 790 38 2780 19 970 : ~ 9 ~ zaaa '' 40 2930 20 1000 9.5 790 ~ ~ 42 3070 10 790 w tsoo a 1000 500 0 e z o z e s o o , z B arrels 3 a o s S hut- ,o , In tim PIT P s e, M i t inut es Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back (CASIN G TEST -LEAK-OFF TEST O o n s s s s Comments: Tested casing after bumping plugs on cement jol 1 J ConocoPhillips Casing Detail 7 5/8" Casing i Well: CD2-75 Date: 5/18/2008 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 33.77 FMC Gen V Hanger 2.64 33.77 Jts 366 to 367 2 Jts 7 5/8" 29.7# L-80 BTCM Csg 85.94 36.41 Pup jt. 7 5/8" 29.7# L-80 BTCM Csg 12.20 122.35 Jts 187 to 365 179 Jts 7 5/8" 29.7# L-80 BTCM Csg 7637.82 134.55 Halliburton Stage Collar 2.38 7772.37 Jts 4 to 186 183 Jts 7 5/8" 29.7# L-80 BTCM Csg 7794.19 7774.75 Halliburton Baffle Collar 1.35 15568.94 Jts 3 to 3 1 Jts 7 5/8" 29.7# L-80 BTCM Csg 42.94 15570.29 Halliburton Float Collar 1.00 15613.23 Jts 1 to 2 2 Jts 7 5/8" 29.7# L-80 BTCM Csg 86.11 15614.23 Silver Bullet Float Shoe 2.10 15700.34 7 5/8" Shoe@ 15702.44 9 7/8" Hole TD @15,717 ' MD /7372 'TVD 7 5/8" Shoe @15,702.44 ' MD / 7370' TVD Total Centralizers: 77 Straight blade centralizer one per jt on jts # 1-20 Straight blade centralizer one per jt f/ 186 to 203 Straight blade centralizer on jts # 290, 291, 292 Straight blade centralizer one per jt on every other joint From jt # 294 thru jt # 364 385 joints in shed - 367 total jts. to run Last 18 jts. out Use Run & Seal i e do e Average MU torque ft/Ibs Remarks: Up Wt - 410 k + DnWt-150k Block Wt - 75k Supervisor: Mickey /Hill /Wilson ~ ~ C~ Cement Detail Report 4 }Y~ t CD2-75 ... . Production Casing Cement _ -, Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 5/18/2008 05:00 5/18/2008 10:30 CD2-75 Comment Cementjob was performed in 2 stages - @nd stage pumped through HES stage collar @ 7772' _ -- - _ Cement Stages __ _ _ _ Stake # 1 _ Description _ _ Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Production Casing 13,300.0 15,702.0 Yes 0.0 Yes Yes Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 390.0 900.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented 1st stage as follows, dropped wiper dart then pumped 10 bbls CW 100; pressure tested lines to 4,000 psi, loaded displacement dart and fin. pumping 30 bbls (40 total) of CW 100 at 8.3 ppg, ave 4 bpm at 415 psi., then pumped 40 bbls of MudPush at 10.5 ppg, 4 bpm and 400 psi. Mixed and pumped 112 bbls (176 sxs) of LiteCrete lead cmt at 11.0 ppg and 3.35 yield w/additives, ave 6.2 bpm, ICP 590 psi, FCP 435 psi., followed with 36.6 bbls (164 sxs) of class "G" tail cmt at 15.8 ppg and 1.16 yield w/additives, ave 4.5 bpm at 210 psi. Dropped displacement dart and Dowell pumped 20 bbls water then turned over to rig and rig fin. displacing cmt with 695 bbls of 10.2 ppg LSND mud, ave. 7 bpm, ICP 400 psi, max press. 650 psi, with 20 bbls to go slowed to 3.5 bpm at 390 psi and bumped plug to 900 psi. CIP @ 07:50 hrs, had full returns, checked floats and held. Calc TOC @ 13,300'. - _ Cement Fluids 8~ Additives Fluid __ __ _ _ __ Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 13,300.0 15,168.0 174 G 112.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 3.35 11.22 11.50 Additives Additive Type Concentration Conc Unit label Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbp Tail Cement 15,168.0 15,702.0 153 G 36.6 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Stage # 2 __ - - -- - - Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Production Casing 6,719.0 7,772.0 Yes Yes No Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 380.0 1,700.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cemented 2nd stage as follows, pumped 20 bbls of CW 100 at an ave 4 bpm at 180 psi and followed with 30 bbls of MudPush at 10.5 ppg, 4.5 bpm at 200 psi. Then mixed and pumped 58.5 bbls, (274 sxs) of class "G" tail cmt at 15.8 ppg, 1.17 yield w/additives, ave 4.5 bpm, ICP 190 psi, FCP 130 psi. Dropped closing plug and Dowell pumped 20 bbls water then the rig displaced cement with 337 bbls of 10.2 ppg mud, ave 7 bpm, ICP 200 psi, FCP 380 psi, with 20 bbls left in displacement slowed to 3.5 bpm at 240 psi, bumped plug to 1,700 psi and closed HES cementer. CIP at 10:20 hrs, bled off press. and tool was closed, had full returns throught the job and calc. TOC is at 6,719'. __ _ - - _ Cement Fluids & Additives _ __ Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 6,719.0 7,772.0 164 G 36.6 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.09 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 6/13/2008 • Security Level: ~~- Daily Drilling Report ,.~ ~„ ~.t CD2-75 . ~ - Report Number: 15 Rig: DOYON 19 Report Date: 5/18/2008 ~_ AFE Type - - -- -- - Network/ID # ', Total AFE+Sup Drilling 10218060 11,248,054.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK6) Depth End (ftK6) CD2-75 Development ALPINE 12.53 15.0 0.00 15,717.0 15,717.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,642.55 506,070.02 857,883.55 4,265,748.02 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/4/2008 5/6/2008 36.98 30.79 6.19 6/4/200810:31 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 15,702.OftKB Ops and Depth ~ Morning Report 24hr Forecast Testing BOPE Fin. testing BOPE, MU 6 3/4" bit, RIH PU 4" DP, drill out stage tool & cont. RIH Last 24hr Summary Fin RIH w/7 5/8" csg & landed same at 15,702'. Circ & cond. mud then cmt'd csg in 2 stages w/no problems (did not reciprocate csg). Rd cmt equip & installed 7 5/8" packoff & tested same. Changed out 7 5/8" csg rams back to VBR's & began LD 5" DP out of the derrick thru the mousehole. General Remarks Weather Head Count No Accidents and No Spills 25 Deg, WC 15, Overcast, Wind E @ 7 mph 49.0 Supervisor ~-- --- Title Don Mickey, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor Peter Wilson, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log ___ Start End Dur _ _ Time - Depth Start ; - Depth End Time Time (hrs) phase Op Code OpSub-Code I P-N-T Trbl Code ' Trbl Class (ftK8) I (ftKB) Operation 00:00 02:15 2.25 INTRM1 CASING RNCS P 13,642.0 15,702.0 Cont. RIH with 7 5/8" csg f/13,642', MU FMC fluted hanger and landed csg w/ shoe @ 15,702' - FC @ 15,613' - BafFle collar @ 15,669' -Stage collar @ 7772' - SO wt 150K Ran a total of 367 jts and 1-12' pup of 7 5/8", 29.7#, L-80, BTCM csg, total including float equip and hanger 15,668.67' 02:15 02:45 0.50 INTRM1 CASING RURD P 15,702.0 15,702.0 RD Franks fill up tool, blow down top drive and MU Dowell cement head. 02:45 04:45 2.00 INTRM1 CEMENT CIRC P 15,702.0 15,702.0 Circ and cond. mud for cementing staged pump rate up from 2.5 bpm at 440 psi to 7 bpm at 670 psi, circ 10.2 ppg MW in, held PJSM while circ hole and did not reciprocate pipe. Latest BOP Test Data - - --- Date --- 1 Comment .. _ 5/9/2008 250/2500/3500 Page 1/3 Report Printed: 6/12/2008 • Security Level: _. Daily Drilling Report CD2-75 Report Number: 15 ... . Rig: DOYON 19 Report Date: 5/18/2008 Time Log _ _ _ Start End ~ _ __ Dur - j Time Depth Start DepthEnd Time Time ~. (hrs) Phase ~' Op Code OpSub-Code ~ P-N-T Trbl Code Ttbl Class. (ftK6) (ftKB) Operation 04:45 08:00 3.25 INTRM1 CEMENT DISP P 15,702.0 15,702.0 Cemented 1st stage as follows, dropped wiper dart then pumped 10 bbls CW 100, pressure tested lines to 4,000 psi, loaded displacement dart and fin. pumping 30 bbls (40 total) of CW 100 at 8.3 ppg, ave 4 bpm at 415 psi., then pumped 40 bbls of MudPush at 10.5 ppg, 4 bpm and 400 psi. Mixed and pumped 112 bbls (176 sxs) of LiteCrete lead cmt at 11.0 ppg and 3.35 yield w/additives, ave 6.2 bpm, ICP 590 psi, FCP 435 psi., followed with 36.6 bbls (164 sxs) of class "G" tail cmt at 15.8 ppg and 1.16 yield w/additives, ave 4.5 bpm at 210 psi. Dropped displacement dart and Dowell pumped 20 bbls water then turned over to rig and rig fin. displacing cmt with 695 bbls of 10.2 ppg LSND mud, ave. 7 bpm, ICP 400 psi, max press. 650 psi, with 20 bbls to go slowed to 3.5 bpm at 390 psi and bumped plug to 900 psi. CIP @ 07:50 hrs, had full returns, checked floats and held. Calc TOC @ 13,300'. 08:00 09:00 1.00 INTRM1 CEMENT CIRC P 15,702.0 15,702.0 Loaded 2nd stage closing plug then pressured up to 3,200 psi opening the HES cementer, circ btms up at 7 bpm at 330 psi. 10.2 ppg MW in and out. 09:00 10:30 1.50 INTRM1 CEMENT DISP P 15,702.0 15,702.0 Cemented 2nd stage as follows, pumped 20 bbls of CW 100 at an ave 4 bpm at 180 psi and followed with 30 bbls of MudPush at 10.5 ppg, 4.5 bpm at 200 psi. Then mixed and pumped 58.5 bbls, (274 sxs) of class "G" tail cmt at 15.8 ppg, 1.17 yield w/additives, ave 4.5 bpm, ICP 190 psi, FCP 130 psi. Dropped closing plug and Dowell pumped 20 bbls water then the rig displaced cement with 337 bbls of 10.2 ppg mud, ave 7 bpm, ICP 200 psi, FCP 380 psi, with 20 bbls left in displacement slowed to 3.5 bpm at 240 psi, bumped plug to 1,700 psi and closed HES cementer. CIP at 10:20 hrs, bled off press. and tool was closed, had full returns throught the job and calc. TOC is at 6,719'. 10:30 11:30 1.00 INTRM1 CEMENT RURD P 15,702.0 15,702.0 Blow down lines - RD cmt lines & cmt head - LD landing jt. 11:30 12:00 0.50 INTRM1 CEMENT OTHR P 15,702.0 15,702.0 Drain stack -Pull thin wall wear bushing 12:00 12:30 0.50 INTRMI CASING NUND P 15,702.0 0.0 Set packoff and tested 5000 psi. OK. 12:30 14:00 1.50 INTRM1 CASING NUND P 0.0 0.0 Changed 7 5/8" rams to VBR. RD casing tools. 14:00 00:00 10.00 INTRM1 DRILL PULD P 0.0 0.0 PJSM and laid down 5" DP from derrick via mousehole. - ___ - ___ Injection Fluid Fluid Source From Lease (bbl) Destination Note ,. _ _ __ _ Diesel CD2-75 5.0 CD2-72 Page 2/3 Report Printed: 6/12/2008 • • Security Level: Ez ' F=~ } Daily Drilling Report h :'~ f ~~a CD2-75 Report Number: 15 .. .• Rig: DOYON 19 Report Date: 5/18/2008 irnfeCtlOn. FlUld i uid Source From Lease (bbp Destination -- , Note - __ iWater Based Mud CD2-75 2280.0 CD2 72 - Wellbores - - - - -- --- Wellbore Name - Wellbore API/UWI - - CD2-75 ~ 501032057300 __ Section I Size (in) ' Act Top (ftKB) '~. Act Btm (ftKBj I- Start Date End Date COND1 36 SURFAC 13 1/2 ____ 36.0 114.0 2/20/2008 114.0 3,363.0 5/6/2008 - -- 2/21/2008 5/8/2008 INTRM1 9 7/8 3,363.0 15,717.0 5/10/2008 5/15/2008 PROD1 6 3/4 15,717.0 23,539.0 5/22/2008 5/27/2008 Casin Strin s _ Casin Descn tion ~ Run Date ~ 9 p_ OD (in) ~ Wt Qbsttt) Grade _~ Set Depth (ftKB) _ Comment Intermediate 5/18/2008 7 5/8~ 29.70 L-80 15,702.0 _ . -- .Cement - - _ Production Casin Cement -Started 5/18/2008 ___ Type Wellbore Cemented String Cement Evaluation Results casing CD2-75 Intermediate, 15,7 02.OftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Production Casing Cement 15,702.0 13,30 0.0 4 390.0 Fluid Class Amo . unt (sacks) ', V (bbl) Density Qb/gaq Yield (ft'lsack) Est Top (ftKB) Est Btm (ftKB) Lead Cement G 174 112.0 11.50 3.35 13,300.0 15,168.0 Tail Cement G 153 36.6 15.80 1.16 15,168.0 15,702.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 2 Production Casing Cement 6,719.0 7,772.0 4 380.0 Fluid I Ctass Amount (sacks] V (bbl) '. Density Qblgal) Yield (ft'/sack) j _ Est Top (ftKB) ~ Esi Btm (ftKB) Tail Cement G 164 36 6 15.80 1.17 6,719.0 7,772.0 t d~ ;1' e. Page 3/3 Report Printed: 6/12/2008 Well Name: CD2-75 Rig: Drilling Supervisor: D. Mickey Type of Test: Annulus Leak Off or Disposal Adequacy Hole Size: 9-~/$" ~ ing Shoe RKB-CHF: 36.0 Ft 3,353 Casing Size and Description: 9-5/s" 3 ~ Chan es for Annula r Ade u ac Tes outer casing shoe test result: in comments Description references oute casing string ize is that drilled below oute casing. timated TOC for Hole Depth, Enter inner casing OD at righ PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 5/20/2008 Volume Input Pump used: Cement Unit ~ Barrels ~ ~ Pumping down annulus. ~ Casi ~ Hole Depth Pumping BTC er casing OD Desired PIT Estimates for Tes ~~ = Leak-off Pressure + Mud Weight = 1040 0.052 x TVD 0.052 x 2390 +~ _,~,~ ,t EMW at 3353 Ft-MD (2390 Ft-TVD) = 15.3 ~~ ~ ~~~~~ ~.,..,. ~ ~~ r iooo w Q: w a soo PP9 In. PP9 psi 0.8 bbls Bbls/Strk ~ st Pn Shut-in Pur lin psi Bbls 0 0 1 2 1 15 20 Pump Rate: 0.8 Bbl/min ~ re Integrity Te 91 5.5 101 6 104 6.5 105 7 105 7.5 10E 8 105 8.5 10? 9 104 0 1022 .25 996 0.5 982 1 969 1.5 962 3.5 950 4 943 4.5 943 5 940 5.5 940 o f a a' a ~ + + ~ ~ ~~ 0 1 2 3 4 5 6 7 8 9 10 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Vol ~~CASING TEST (LEAK-OFF TEST O PIT Point Pum ed Bled Back Pum ed Bled s s s ;: 10 3/4" LOT/FIT 17.8 ppc Diesel to 1830 ' MD - 1667' TVD water f/ 1830' to 3354' - 2390' TVC PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-75 Rig: Doyon 19 Date: 5/19/2008 Volume Inpu Drilling Supervisor: Mickey /Hill /Wilson Pump used: 'Cement Unit ~ Barrels ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ % Pumping down 'annulus. ~ Cas Hole Size: $-1/2" ~ Casin Shoe De th Hole Depth Pumping 0 Ft RKB-CHF: 36 353 Ft-MD 2,390 3 Ft-TV 6,719 Ft-MD 3,843 Ft-TVD Bbls psi , . Casinq Size and Description: 9-5/8" 36#/Ft J-55 BTC ~ Chan es for Annula r Ade u ac Tes Pressure Int e ri Tes t shoe test result. outer casin in comments Mud Weight: 10.1 ppg g tion references oute Descri casing string Inner casing OD 7.0 In. p ize is that drilled below oute casing timated TOC for Hole Depth . Enter inner casing OD at righ Desired PIT EMW: 14.5 ppg Estimates for Test: 547 psi 0.4 bbls ~ + 889 EMW =Leak-off Pressure + Mud Weight = PIT 15 Second 052 x TVD 0.052 x 0 2390 + 10.1 Shut-in Pressure, psi . EMW at 3353 Ft-MD (2390 Ft-TVD) = 17.3 _ _627 iooo w N soo w a Pump Rate: _ Bbls/Strk ~ ~ 0.8 ebl/min ~ Est Pressure In te ri Tes1 Shu t-in Pumping Shut-in in psi Bbls psi Min psi 0 0 0 0 660 1 1 136 0.25 627 2 2 246 0.5 612 3 3 318 1 598 4 4 387 1.5 587 5 5 453 2 583 6 6 503 2.5 576 620~~ 3.5~ 571 15 11 797 20 12 852 5.5 0 Volume Volume Volume Vol 0 5 10 Barrels zo ze so ss o Shut-In time, Minutes so CASING TEST ~-LEAK-OFF TEST O PIT Point PUm ed Bled Back PUm ed Bled S S S s: ~ ppc -~ - S~'© i ~ \ - ~Lf\~, _ ~, \J~S\ ~w _ _- •I PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-75 Rig; Doyon 19 Date: 5/20/2008 Volume Input _ Pump Rate: Drilling Supervisor: D. Mickey Pump used: ~ Cement Unit ~ Barrels ~ Bbls/Strk ~ 0.8 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ ': Pumping down ~ annulus. ~ Casin Test Pressure Inte rity Test Hole Size: 9-~/$" ~ ~' Casin Shoe Depth Hole Depth Pumpin Shut-in Pumpin Shut-in 353 Ft-MD 2,390 Ft-TV 0 Ft 3 RKB-CHF: 36 6,719 Ft-MD 3,843 Ft-TVD Bbls psi Min psi Bbls psi Min psi , . Casing Size and Description: 9-s/a" 36#/Ft J-55 BTC ~ O 0 550 0 1022 Chan es for Annula outer casing shoe test result: r Ade u ac Tes in comments Pressure Int Mud Weight: e ri Tes 7.3 1 ppg 1 2 0.5 1 624 680 0.25 0.5 996 982 Description references oute casing string Inner casing OD 7.6 In. 3 1.5 723 1 969 ize is that drilled below oute casing. 4 2 754 1.5 962 timated TOC for Hole Depth 5 2.5 792 2 956 Enter inner casing OD at righ Desired PIT EMW: 14.5 ppg 6 3 843 2.5 950 Estimates for Test: 900 psi 0.7 bbls 7 3.5 880 3 950 ~ . ~' 8 4 914 3.5 950 1040 EMW =Leak-off Pressure + Mud Weight = PIT 15 Second 9 4.5 954 4 943 + 7 26 052 x TVD 0.052 x 2390 0 Shut-in Pressure, psi 10 5 976 4.5 943 . EMW at 3353 Ft-MD (2390 Ft-TVD) = 15.6 ~ _ 996 15 5.5 1010 5 940 _ 20 6 1040 5.5 940 ,soo 25 6.5 1055 6 943 30 7 1054 6.5 938 7.5 1064 7 937 - ~ 8 1055 7.5 936 - `; ~ 8.5 1038 8 937 ,ooo i ":!~~, ~ 9 1040 8.5 935 w ~ 9.5 1018 9 935 ~ 9 5 933 . ~ 10 933 w a soo 0 , 5 z o z s s o o , z s a Barrel s s s ~ s s ,0 0 S 5 , hut-I o n tim PIT P e, M i t inute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back CASI NG TES T -LE AK-OFF TEST O o n s s s s omments: pP9 Diesel to 1830' MD - 1667' TVD, water f/ 1830' MD to 3354' MD/2390' TVC u • Pressure Integrity Test CD2-75 1500 li 1000 W N W ~' a 500 ie re ne 0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 9.0 1 0.0 Barrels i • Time L s Date From To Dur S. De h E. De th Phase Code Subcode T Comment 07:00 10:30 3.50 3,396 6,812 INTRM1 CASING RNCS P Cont. to run 7 5/8" 29.7# L-80 BTCM f/ 3396' to 6812' 160 'ts total 10:30 12:00 1.50 6,812 6,812 INTRM1 CASING CIRC P Break circ & stage pump up to 6 BPM &circ btms up + @ 6 BPM @ 500 si - PU wt. 195 SO wt 140 12:00 16:00 4.00 6,812 10,240 INTRM1 CASING RNCS P Cont. running 7 5/8" 29.7# L-80 BTCM casing f/ 6812' to 7927' (186 jts total) Install Halliburton Stage collar (made up w/BakerLoc) - Continue running 7 5/8' 29.7# L-80 BTCM casing f/ 7927' to 10,240' (240 total 'ts in hole of 367 to run 16:00 17:45 1.75 10,240 10,240 INTRM1 CASING CIRC P Break circ & stage pump up to 6 BPM @ 460 psi &Circ btms-up +. PU wt 315K, SO wt 148K 17:45 21:45 4.00 10,240 13,642 INTRMI CASING RNCS P Cont. running 7 5/8" 29.7# L-80 BTCM casing f/ 10,240' to 13,642' 320 total 'ts in hole of 367 to run . 21:45 00:00 2.25 13,642 13,642 INTRM1 CASING CIRC P Circ btms up + staging pump rate up to 6.5 bpm at 650 psi, PU wt 410K, SO wt 160K 5/18/2008 Fin RIH w/7 5/8" csg & landed same at 15,702'. Circ & cond. mud then cmt'd csg in 2 stages w/no problems (did not reciprocate csg). Rd cmt equip & installed 7 5/8" packoff & tested same. Changed out 7 5/8" csg rams back to VBR's & be an LD 5" DP out of the derrick thru the mousehole. 00:00 02:15 2.25 13,642 15,702 INTRM1 CASING RNCS P Cont. RIH with 7 5/8" csg f/13,642', MU FMC fluted hanger and landed csg w/ shoe @ 15,702' - FC @ 15,613' -Baffle collar @ 15,669' - Stage collar @ 7772' - SO wt 150K Ran a total of 367 jts and 1-12' pup of 7 5/8", 29.7#, L-80, BTCM csg, total including float equip and hanger 15,668.67' 02:15 02:45 0.50 15,702 15,702 INTRM1 CASING RURD P RD Franks fill up tool, blow down top drive and MU Dowell cement head. 02:45 04:45 2.00 15,702 15,702 INTRM1 CEMEN' CIRC P Circ and cond. mud for cementing staged pump rate up from 2.5 bpm at 440 psi to 7 bpm at 670 psi, circ 10.2 ppg MW in, held PJSM while circ hole and did not reciprocate i e. Page 1 Q of 24 • Time1C s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:45 08:00 3.25 15,702 15,702 INTRMI CEMEN" DISP P Cemented 1st stage as follows, dropped wiper dart then pumped 10 bbls CW 100, pressure tested lines to 4,000 psi, loaded displacement dart and fin. pumping 30 bbls (40 total) of CW 100 at 8.3 ppg, ave 4 bpm at 415 psi., then pumped 40 bbls of MudPush at 10.5 ppg, 4 bpm and 400 psi. Mixed and pumped 112 bbls (176 sxs) of LiteCrete lead cmt at 11.0 ppg and 3.35 yield w/additives, ave 6.2 bpm, ICP 590 psi, FCP 435 psi., followed with 36.6 bbls (164 sxs) of class "G" tail cmt at 15.8 ppg and 1.16 yield w/additives, ave 4.5 bpm at 210 psi. Dropped displacement dart and Dowell pumped 20 bbls water then turned over to rig and rig fin. displacing cmt with 695 bbls of 10.2 ppg LSND mud, ave. 7 bpm, ICP 400 psi, max press. 650 psi, with 20 bbls to go slowed to 3.5 bpm at 390 psi and bumped plug to 900 psi. CIP @ 07:50 hrs, had full returns, checked floats and held. Calc TOC 13,300'. 08:00 09:00 1.00 15,702 15,702 INTRM1 CEMEN' CIRC P Loaded 2nd stage closing plug then pressured up to 3,200 psi opening the HES cementer, circ btms up at 7 bpm at 330 psi. 10.2 ppg MW in and out. 09:00 10:30 '1.50 15,702 15,702 INTRM1 CEMEN' DISP P Cemented 2nd stage as follows, pumped 20 bbls of CW 100 at an ave 4 bpm at 180 psi and followed with 30 bbls of MudPush at 10.5 ppg, 4.5 bpm at 200 psi. Then mixed and pumped 58.5 bbls, (274 sxs) of class "G" tail cmt at 15.8 ppg, 1.17 yield w/additives, ave 4.5 bpm, ICP 190 psi, FCP 130 psi. Dropped closing plug and Dowell pumped 20 bbls water then the rig displaced cement with 337 bbls of 10.2 ppg mud, ave 7 bpm, ICP 200 psi, FCP 380 psi, with 20 bbls left in displacement slowed to 3.5 bpm at 240 psi, bumped plug to 1,700 psi and closed HES cementer. CIP at 10:20 hrs, bled off press. and tool was closed, had full returns throught the job and calc. TOC is at 6,719'. 10:30 11:30 1.00 15,702 15,702 INTRM1 CEMEN' RURD P Blow down lines - RD cmt lines & cmt head - LD landin 't. 11:30 12:00 0.50 15,702 15,702 INTRMI CEMEN " OTHR P Drain stack -Pull thin wall wear bushin 12:00 12:30 0.50 15,702 0 INTRM1 CASING NUND P Set packoff and tested 5000 psi. OK. Page 11 of 24 • Time Lp s Date ... From To Dur S. De th E. pe th Phase Code Subcode T Comment 12:30 14:00 1.50 0 0 INTRM1 CASING NUND P Changed 7 5/8" rams to VBR. RD casin tools. 14:00 00:00 10.00 0 0 INTRM1 DRILL PULD P PJSM and laid down 5" DP from derrick via mousehole. 5/19/2008 Finish LD 5" DP - RU & Tested ROPE 250/3,500 psi, Chuck Scheve WlAOGCC waived witnessing of test - MU BHA #3 -RIH PU 4" DP to 7,700'-Slip & cut drlg line -Test csg above stage toot 3,500 psi f/10 min - Drilled out sta a tool 7,772'-7,775', washin down at 7,795'. 00:00 04:45 4.75 0 0 INTRM1 DRILL PULD P Finish laying down 5" DP f/ derrick via mouse hole LD 486 'ts total 04:45 10:30 5.75 0 0 INTRM1 WELCTL BOPE P RU & Test BOPE - Annular to 250 & 2500 psi -Pipe rams, choke & kill line valves, choke manifold valves, TD IBOP valves, floor safeyt & dart valves, blind rams to 250 & 3500 psi - performed accumulcator closure test -tested VBR's with 3 1/2" & 4 1/2" test jts. for liner & tbg runs - RD. NOTE: Chuck Scheve W/AOGCC waived witnessin of the test. 10:30 10:45 0.25 0 0 INTRM1 DRILL OTHR P Install wear bushing 10:45 11:30 0.75 0 0 INTRM1 DRILL PULD P PU & std back 5 stds of 4" DP 11:30 12:30 1.00 0 287 INTRM1 DRILL PULD P MU BHA #3 (clean out assembly) bit -BS-stab-3NMDC's-XO-3jts HWDP - 'ars - 2 'ts. HWDP to 287' 12:30 18:15 5.75 287 7,700 INTRM1 DRILL TRIP P RIH w/ BHA # 3 f/ 287' -picking up 4" DP f/ pi a shed RIH to 7,700' 18:15 18:45 0.50 7,700 7,700 INTRM1 DRILL CIRC P Circ a DP volume at 6 bpm, 950 psi and 60 r m's 18:45 20:15 1.50 7,700 7,700 INTRM1 RIGMNT SVRG P Held PJSM then slip and cut 120' of drlg line then serviced top drive. Tested 7 5/8" csg above stage tool to _ min and ck'd ok. 20:15 00:00 3.75 7,700 7,795 INTRMI CEMEN" DRLG P Washed down from 7,700' and tagged plug above HES cementer/stage collar, drilled out stage collar from 7,772' to 7,775' and cont. to wash down to 7,795'. 5/20/2008 Wash /Ream & RIH f/ 7795' - 15525' MD; Pulled Up t/ 15515' and Tested 7 5/8" Casing. to 3500 qsi f/ 30 Minutes Good); Drill Float Collar i£ 8' of New Hole f/ 15515' -15725' MD; Circulated Bottoms Up, Observed Well for Flow Static ,and Pumped /Pulled Out-of--Hole f/ 15725' - 12760' MD 00:00 01:00 1.00 7,795 7,700 INTRM1 DRILL REAM P Cont. was & ream f/ 7795' to 7986' w/300 gpm @ 1130 psi -100 rpm's PU wt. 185 SO wt. 110 Rot wt. 135 Pull & std back 3 stds DP to 7700' - Blow down TD 01:00 02:15 1.25 7,700 8,747 INTRM1 DRILL TRIP P RIH f/ 7700' to 8747' -picking up 4" DP f/ pipe shed Took wt. 8747' 02:15 03:30 1.25 8,747 8,747 INTRM1 DRILL REAM T Wash & ream f/ 8747' to 9030' w/ stds f/derrick w/ 7 bbls/min @ 1230 psi w/ 110 rpm's PU wt. 195 SO wt. 110 Rot wt. 135 - POOH & std back 3 stds -Blow down TD Page 12 pf 24 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment ' 03:30 07:00 3.50 8,747 12,940 I NTRM1 DRILL TRIP P picking Cont. RIH f/ 8747' to 12,940 up 4" DP f/ pipe shed - took wt. @ 12,940' 07:00 07:30 0.50 12,940 12,951 I NTRMI DRILL REAM T Wash & ream f/ 12,855' to 12,951' - Blow down TD 07:30 10:15 2.75 12,951 15,332 I NTRM1 DRILL TRIP P Cont. RIH f/ 12,951' to 15,332' - picking up 4" DP f/ pipe shed -all DP picked u for this run 10:15 10:30 0.25 15,332 15,525 INTRM1 DRILL TRIP P RIH f/ 15,332' w/ DP f/ derrick to 15,525' to ed to of cmt 10:30 12:00 1.50 15,525 15,515 INTRM1 DRILL CIRC P Break circ &circ for casing test - Pull up to 15,515' - RU for casing test 12:00 13:00 1.00 15,515 15,515 INTRMI DRILL OTHR P Test 7 5/8" casing to 3500 psi for 30 mins Good Test - RD 13:00 17:00 4.00 15,515 15,725 INTRM1 DRILL DRLG P Clean out shoe track -Drilled baffle collar @ 15,569', cmt to FC @ 15,613' -drilled FC to 15614' -clean out cmt to top of FS @ 15700' - Drilled out FS to 15,702' -Clean out rat hole to 15,717' -Drilled 8' of New Hole f/ 15515' - 15725' MD; 325 GPM @ 2200 psi; 100 RPM - Had no problem drilling through hard spot @ 15,717' 17:00 18:15 1.25 15,725 15,725 INTRM1 DRILL CIRC P CBU; 325 GPM @ 2300 psi; Rot / Recip Pipe 100 RPM 18:15 18:30 0.25 15,725 15,725 INTRM1 DRILL OWFF P Flow check -well static 18:30 20:00 1.50 15,725 14,673 INTRM1 DRILL TRIP P Pump Out of Hole f/ 15725' -14673' MD 20:00 20:15 0.25 14,673 14,673 INTRM1 DRILL OWFF P Flow check (Static); Blow Down Top Drive 20:15 22:15 2.00 14,673 13,620 INTRM1 DRILL TRIP P POOH on TT f/ 14673' -13620' MD; Pumped D Job 13716' MD 22:15 22:45 0.50 13,620 13,620 INTRM1 RIGMNT SVRG P Rig Service 22:45 00:00 1.25 13,620 12,760 INTRM1 DRILL TRIP P POOH f/ 13620' - 12760' MD; P/U 270, S/O 125 5/21 /2008 Continued to POOH w/ Clean out BHA and Lay Down Same; P/U BHA #4 6 3/4" Bit, Geo-Pilot, MWD, Geo Tap, Non-Magnetic Float Sub, Non-Magnetic Flexible Drill Collars, Hevi-Wate Drill Pipe, and Drilling Jars; RIH f/ 382' -15614' MD w/ 261 Jts (87 Stds) of 4" DP f/ Pipe Shed then 73 Stds of 4" DP f/ the Derrick Filling Pipe Eve 20 Stands; Cut & Sli 60' 8 Wraps of 1 3/8" Dia. Drill Line 00:00 08:30 8.50 12,760 287 INTRM1 DRILL TRIP P Cont. POOH on TT f/ 12760' to 287' HWDP -Flow ck -static 08:30 09:15 0.75 287 0 INTRM1 DRILL PULD P SB HWDP & Jars - LD XO - PU & break bit - LD stab & std back NMDC's 09:15 11:30 2.25 0 98 INTRMI DRILL PULD P MU BHA #4 - GeoPilot -MWD - GeoTap - Up load MWD -Pressure test Geos an 11:30 12:00 0.50 98 382 INTRM1 DRILL PULD P MU NM float sub - NM flex DC's - HWDP & Jars -shallow test MWD- MU 1 std HWDP 12:00 19:30 7.50 382 8,671 INTRM1 DRILL TRIP P RIH w/ BHA #4 f/ 382' to 8671' MD - pickin up 4" DP f/ pi a shed Page 13 of 24 ConocoPhillips June 26, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-75 Dear Commissioner: G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 O'S35x-,~ r^,~~ ~ll:;~ { ,, .., 1~ V,~~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-75. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad STATE OF ALASKA ~ JILL ®~. ZOOS ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION R°~~'~1~,L~:~~10#1 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. I CYass: Development ^ / Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., orAband.: June 1, 2008 ~ 12. Permit to Drill Number: 208-064/ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 6, 2008 13. API Number: 50-103-20573-00 • 4a. Location of Well (Governmental Section): Surface: 2215' FNL, 2043' FEL, Sec. 2, T11 N, R4E, UM 7. Date TD Reached: May 27, 2008 ~ 14. Well Name and Number: CD2-75 ' Top of Productive Horizon: 1111' FNL, 2041' FWL, Sec. 9, T11 N, R4E, UM 8. KB (ft above MSL): f;~,3 Ground (ft MSL): .a2:S'AMSL/$: 15. Field/Pool(s): /" ~',C~ Colville River Field Total Depth: 499' FSL, 2010' FEL, Sec. 32, T12N, R4E, UM 9. Plug Back Depth (MD + ND): 15702' MD / 7370' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371190 ' y- 5974151 • Zone- 4 ~ 10. Total Depth (MD + ND): ~~~ ~ ' (~j, ~ 2~' MD / 7 ' N ~ 16. Property Designation: A D L ,7$GO Aa ~ ~ktC'J87207, ASRCNPRA02 TPI: x- 359370 y- 5970187 Zone- 4 Total Depth: x- 355432 - 5977153 Zone- 4 11. SSSV Depth (MD + ND): ~ 2196' MD / 1875' TVD 17. Land Use Permit: .1.$• b 18. Directional Survey: Yes ^~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1503' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 5.5 sx Portland Type III 10.75" 45.5# L-80 37' 3353' 37' 2390' 13.5" 525 sx Class G, 280 sx Class G 7-5/8" 29.7# L-80 37' 15702' 37' 7370' 9-7/8" 174 sx Class G, 153 sx Class G, 164 sx Class G 4.5" 12.6# L-80 12862' 21202' 6509' 7366' 6.75" blank liner with pert pups ` 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 12882' 12734' perforated liner from 13761'- 21155' MD 6863'-7366' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production June 7, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 6/13/2008 Hours Tested 8 hours Production for Test Period -> OIL-BBL 1455 GAS-MCF 1009 WATER-BBL 15 CHOKE SIZE 100 Bean GAS-OIL RATIO 915 Flow Tubing press. 290 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 4149 ~ GAS-MCF 2797 WATER-BBL 46 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ^/ - Sidewall Cores Acquired? Yes No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. CUtV~pi cTIO~E C NONE ~ ~ ~D~7E '1-fRl IED Form 10-407 Revised 2/2007 CONTIN 61DH ~~ ~ €~ L~Do ORIGINAL &IU 0 '~~~ ~ ~c~-~~ ~ ~.g.~ ~ 28. GEOLOGIC MARKERS (List all formations and mar ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1600' 1503' needed, and submit detailed test information per 20 AAC 25.071. K-3 6693' 3836' K-2 7216' 4065' Nanuq 11261' 5816' K-1 14586' 7132' Kuparuk C 14749' 7176' Alpine 15460' 7332' N/A Formation at total depth: Alpine A ~ 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz Geliunas @ 265-6247 Printed Name i Alvord Title: Drillino Team Leader ~ ~38~? D~ ~ Signature Phone 2G~5 , (' ! LD Dat INSTRUCTIONS Sharon Allsup-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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ConocoPhil~ips Time Log & Summary WelNiew Web ReAVrting Report Well Name: CD2-75 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 5/5/2008 6:30:00 PM Rig Release: 6/2/200812:00:00 PM ~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 5/04/2008 2a hr summary Perp rig for move f/CD3 to CD2 -Begin moving rig componets f/CD3 - 15:30 00:00 8.50 0 0 MIRU MOVE MOB P Prep rig for Move f/CD3-107 to CD2-75 -Begin moving rig componets f/CD3 to CD2 -Moving ball mill -motor & pit complexes & Sub 5/05/2008 Continue rig move f/CD3 to CD2 -Ball mill, motor, & pit complexes on location @CD2 @ 0245 hrs -Sub base on location @ 1300 hrs -Spot rig over well -lower cellar walls -jack floor into drilling position -Spot pit & motor complexes -Hook up service lines -bring rig up on high line power @ 1830 hrs -Modify surface riser -Change hydraulic line in cable tray under rig floor -Load pipe shed w/ 5" DP & HWDP -Bring BHA componets to rig floor (subs, stabs,& XO's) -Install surface riser Acce t ri 1830 hrs. 00:00 16:30 16.50 0 0 MIRU MOVE MOB P Continue rig move f/CD3 to CD2 - Ball mill, motor, & pit complexes on location @CD2 @ 0245 hrs -Sub base on location @ 1300 hrs -Spot rig over well -lower cellar walls -jack floor into drilling position -Spot pit & motor com lexes 16:30 18:30 2.00 0 0 MIRU MOVE RURD P Hook up service lines -bring rig up on hi h line ower 1830 hrs 18:30 21:30 3.00 0 0 SURFA( DRILL RURD P Modify surface riser -Change hydraulic line in cable tray under rig floor -Load pipe shed w! 5" DP & HWDP Acce t ri 1830 hrs. 21:30 22:30 1.00 0 0 SURFA( DRILL PULD P Bring BHA componets to rig floor subs, stabs,& XO's 22:30 00:00 1.50 0 0 SURFAt DRILL RURD P Install surface riser 5/06/2008 PU 5" DP. PU BHA. Drilled 13 1/2" hole from 114' to 1,278'. 00:00 00:30 0.50 SURFA( DRILL RURD P Rigged up riser and connected flowline. 00:30 02:00 1.50 SURFA( DRILL RURD P Loaded pipe shed and preped for ickin u DP. 02:00 06:30 4.50 SURFAt DRILL PULD P PJSM and picked up 5" DP from pipe shed and stood back in derrick. 06:30 09:00 2.50 0 93 SURFA( DRILL PULD P PJSM and picked up BHA. Uploaded MWD. 09:00 09:45 0.75 93 93 SURFA( DRILL SFTY P Held Pre Spud meeting with all hands. 09:45 11:15 1.50 93 114 SURFAt DRILL PULD P Filled hole and checked for leaks. Picked up Flex Collars and washed down to 114'. Papa " of 2A Time Logs Date From To Dur S De th E. D th Ph e Code Subcode T Comment 11:15 12:00 0.75 114 169 SURFA( DRILL DDRL P S udded well drillin~13 1/2" it from 114' to 169' ART .44 hrs, AST 0. hrs, ADT .44 hrs ROT 40 rpm's, WOB: 10K, 450 gpm @ 700 psi PU 95 K, SOW 90 K, ROT 92 K TRO Off Btm/On 5000/5000 ft-Ibs 12:00 00:00 12.00 169 1,278 SURFA( DRILL DDRL P Drilled 13 1/2"directional surface hole from 169' to 1,278' MD 1,237' ND ART 4.17 hrs, AST 3.68 hrs, ADT 7.85 hrs ROT 40 rpm's, WOB: 20/25 K, 550 gpm @ 1380 psi PU 120 K, SOW 11.5 K, ROT 120 K TRO Off Btm/On 5000/7000 ft-Ibs 5/07/2008 Drilled from 1,278' to 3,182'. 00:00 12:00 12.00 1,278 2,400 SURFA( DRILL DDRL P Drilled 13 1/2"directional surface hole with motor from 1278' to 2,400' MD 1,980' ND ART 5.56 hrs, AST 1.89 hrs, ADT 7.45 hrs ROT 50 rpm's, WOB: 25/45 K, 700 gpm @ 2200 psi PU 130 K, SOW 115 K, ROT 125 K TRO Off Btm/On 9000/7500 ft-Ibs 12:00 00:00 12.00 2,400 3,182 SURFAt DRILL DDRL P Drilled 13 1/2"directional surface hole with motor from 2,400' to 3,182' MD 2,318' ND ART 6.53 hrs, AST 1.94 hrs, ADT 8.47 hrs ROT 50 rpm's, WOB: 30/45 K, 700 gpm @ 2310 psi PU 134 K, SOW 116 K, ROT 125 K TRQ Off Btm/On 9500/7500 ft-Ibs 5/08/2008 Drilled from 3,182' to 3,363'. CBU and made Wiper Trip. CBU. POOH and laid down BHA. RU and ran 60 jts 10 3/4" casin . 00:00 01:45 1.75 3,182 3,363 SURFA( DRILL DDRL P Drilled 13 1/2" directional surface hole with mo r fr m ,],82' to 3.363' MD 2 394' ND ART 0.94 hrs, AST 0.67 hrs, ADT 1.61 hrs ROT 50 rpm's, WOB: 35/40 K, 700 gpm @ 2420 psi PU 133 K, SOW 115 K, ROT 125 K TRQ Off Btm/On 8500/7000 ft-Ibs 01:45 02:45 1.00 3,363 3,363 SURFA( DRILL CIRC P Circulate hole clean - 700 gpm / 2240 psi / 50 rpm -flow check well, static 02:45 06:30 3.75 3,363 993 SURFA( DRILL TRIP P Perform wiper trip from 3,363' to 993' - 600 gpm / 1760 psi / 50 rpm - no problems -flow check well, static - blow down to drive 06:30 07:45 1.25 993 3,363 SURFA( DRILL TRIP P RIH from 993' to 3,277' - no problems - precautionary wash and ream to 3,363;' 07:45 08:45 1.00 3,363 3,363 SURFA( DRILL CIRC P Circulate and condition mud - 700 gpm / 2370 psi / 60 rpm -flow check well, static Page 2 ref 2d Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 08:45 12:30 3.75 3,363 67 SURFA( DRILL TRIP P POOH on TT from 3,363 to 67' - stood back hwdp and flex collars - LD UBHO sub 12:30 14:00 1.50 67 0 SURFA( DRILL PULD P Plug into MWD -read tool - LD bit - and BHA components -clear tools from ri floor 14:00 14:45 0.75 0 0 SURFA( CASING RURD P RU to run 10 3/4" casing -attempt to torque fill up tool -grab dies not bitin 14:45 16:45 2.00 0 0 SURFA( RIGMNT SVRG P Replace dies in grabber 16:45 17:30 0.75 0 0 SURFA( CASING RURD P MU fill up tool -Rig up to run casing 17:30 17:45 0.25 0 0 SURFA( CASING SFTY P Held Prejob Safety and Opts meeting with crew 17:45 21:45 4.00 0 1,693 SURFA( CASING RNCS P RIH with 42 jts 10 3/4" 45.5# L-80 BTCM casin to 1,693'. 21:45 22:30 0.75 1,693 1,693 SURFA( CASING CIRC P Circulated casing working pumps up to 6 BPM. FCP 280 psi. PU Wt 137 K SOW 110 K. 22:30 00:00 1.50 1,693 2,425 SURFA( CASING RNCS P RIH with 18 jts 10 3/4" 45.5# L-80 BTCM casin to 2,425'. 5/09/2008 Ran and landed casing to 3,353'. Circulated. Cemented casing. Tested casing to 3000 psi for 30 min. OK. Set test plug and tested BOP. Tested Pipe Rams, Blind Rams, Chokeline and Manifold to 250/3500 psi. Tested Annulur to 250/2500 psi. Tested closing unit. All equipment test good. Witiness of test waived by Bob Noble of AOGCC. Set wear bushin and icked u DP standin it back in the derrick. 00:00 01:15 1.25 2,425 3,353 SURFA( CASING RNCS P RIH with 10 3/4" 45.5# L-80 BTCM casing from 2425' to 3310' (82 jts total) - MU FMC fluted mandrel hanger and LJ -Land casing with shoe 3353.61' & FC 3268.09' 01:15 01:45 0.50 3,353 3,353 SURFA( CEMEN" RURD P RD casing slips and tongs - LD fill up tool -blow down top drive - RU cement head and lines 01:45 03:45 2.00 3,353 3,353 SURFA( CEMEN" CIRC P Circulate and condition mud for cementing - 7 bpm / 400 psi - reciprocated i e with full returns throughout - PJSM -Line up to cementers ~'aga ~ rs~ 24 Time Logs Da e From To Dur S. D th E. De th Ph Cod Subcode T Comment 03:45 06:45 3.00 3,353 3,353 SURFAt CEMEN" DISP P Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.9 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/nut plug marker -Switch over to Dowell - Pumped 3 bbls of FW -tested lines to 3100 psi -pumped 12 bbls FW- Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 5.8 BPM @ 155 psi -Mixed & pumped 433 bbls 10.7 ppg Lead slur ASL @ 7.2 BPM / 182 - 210 psi -Observed nut plug marker @ shakers w/ 418 bbls lead slurry pumped - (pumped down surge can 433 bbls total) Switched to tail slurry -Mixed & pumped 61 bbls 15.8 ppg ~.c e slur (Class G w/ adds @ 5.3 BPM @ 155 psi -Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 292.7 bbls 9.9 ppg mud @ 7 BPM / 330 to 750 psi slowed pump to 4.2 BPM / 600 psi (for the last 6 bbls of displacement) Bumped plug to 1200 psi -Check floats OK - CIP @ 0620 hrs. -Full circulation throu hout 'ob w/ 187 bbls 10.7 cement returns to surface - reciprocated pipe while cementing and first 70 bbls of mud displacement -hole getting sticky - lost 32K SOW -landed casing for remainder of 'ob 06:45 07:45 1.00 3,353 3,353 SURFA( CASING DHEQ P RU and test 10 3/4" casina to 3000 _ si for 30 minutes - RD & blow down lines 07:45 09:00 1.25 0 0 SURFA( CASING RURD P LD -cement head & landing joint - RDcasing elevators and bails - PU ands of GeoS an skid onto ri floor 09:00 11:15 2.25 0 0 SURFAC CASING NUND P PJSM - ND flowline - LD Riser - remove FMC speed head from conductor -Install FMC Unibody wellhead -test M/M seal to 1000 psi for 10 minutes 11:15 13:00 1.75 0 0 SURFA( WELCTL NUND P NU BOPS stack -riser &flowline 13:00 18:00 5.00 0 0 SURFA( WELCTL BOPE P Set test lu and tested BOP. Tested Pipe Rams, Blind Rams, Chokeline and Manifold to 250/3500 psi. Tested Annulur to 250/2500 psi. Tested closing unit. All equipment test good. Witiness of test waived by Bob Noble of AOGCC. Pulled test lu . 18:00 18:30 0.50 0 0 SURFA( DRILL OTHR P Installed long wear bushing. 18:30 00:00 5.50 0 0 SURFA( DRILL PULD P Picked up 5"drill pipe from pipeshed and stood back in the derrick. F~age 4 of 2~ • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 5/10/2008 24 hr summary Picked up and stood back 5" DP. Made up BHA and RIH. Cleaned out shoetrack and rat hole. Drilled 20' to 3,383'. CBU and FIT to 17.8 PPG EMW. Drilled from 3,383' to 4,260'. 00:00 04:00 4.00 0 0 SURFA( DRILL PULD P Pick up 5" drill pipe from shed - stand back pipe in derrick -Total of 108 stands 04:00 05:45 1.75 0 76 SURFA( DRILL PULD P MU BHA #2 -Bit, 7600 Geopilot, NMFC (DM), DGR-PWD, Smart Stab, EWR-HCIM, TM HOC, NMFS - Initialize tools - 05:45 06:45 1.00 76 269 SURFA( DRILL PULD P PU 3 NMFC -RIH with 1 stand hwdp - pressure test Geospan skid to 3500 si -Shallow test tools 06:45 08:45 2.00 269 1,883 SURFA( DRILL PULD P PU jars and RIH w/ 5 stds hwdp - RIH picking up 5"drill pipe from shed to 1883' -Ghost reamers @ 766' & 1819' 08:45 09:15 0.50 1,883 1,883 SURFA( DRILL PULD T Change out Geospan skid do to air leak on re ulator 09:15 11:00 1.75 1,883 1,883 SURFA( RIGMNT SVRG P Slip and cut drilling line -service top drive and drawworks 11:00 12:15 1.25 1,883 3,119 SURFA( DRILL TRIP P Continue to RIH picking up 5"drill i e from 1883' to 3119' 12:15 15:00 2.75 3,119 3,363 SURFA( CEMEN' DRLG P Pressure test Geospan skid to 3500 psi -Wash and ream from 3119' - drill out firm cement from 3256' -drill out wiper plugs, FC, cement and FS, clean out rathole to 3363' 15:00 15:45 0.75 3,363 3,383 SURFA( DRILL DDRL P Drill 9 7/8" hole from 3363' to 3383' - ADT= 0.56 hrs. 700 m / 2140 si / 100 si 15:45 16:15 0.50 3,383 3,383 SURFA( DRILL CIRC P Circulate hole clean for FIT - 650 m / 2040 si / 100 m 16:15 16:45 0.50 3,383 3,383 SURFA( DRILL LOT P RU and perform FIT to 17.8 ppg - (mud wt. in hole 9.8 ppg -applied surface ressure 1000 si 16:45 00:00 7.25 3,383 4,260 INTRMI DRILL DDRL P Drilled 9 7/8"directional hole with Geopilot from 3,383' to 4,260' MD 2,907' TVD ADT 4.25 hrs ROT 90 rpm's, WOB: 5/15 K, 700 gpm @ 1760 psi ECD 10.1 PU 138 K, SOW 120 K, ROT 130 K TRO Off Btm/On 10,000/8,000 ft-Ibs. Changed mud to 9.6 PPG LSND while drillin . 5/11/2008 Drilled from 4260' to 5,878'. Hole packed off. Circulated and cleaned up hole. Drilled from 5,878' to 6,735'. Hole asked off. Circulated and cleaned u hole. Drilled from 6,735' to 6,892'. 00:00 04:45 4.75 4,260 4,926 INTRM1 DRILL DDRL P Drilled 9 7/8"directional hole with Geopilot from 4,260' to 4,926' MD 3,071' TVD ADT 3.04 hrs ROT 135 rpm's, WOB: 8/18 K, 743 gpm @ 2320 psi ECD 11.0 PU 160 K, SOW 110 K, ROT 135 K TRO on/off Btm 11,500/10,000 ft-Ibs. Pumped 35 bbls high vis sweep around @ 4451' -slight increase in cuttin s back - ~ Page a c;f ' ` Time Lo s Date From To Dur S. De th E. De th Pha e Code Subcode T Comment 04:45 05:00 0.25 4,926 4,926 INTRM1 DRILL OTHR T After reaming pass prior to connection @ 4926', hole packed off -worked i e and established circulation -lost 50 bbls of mud to hole 05:00 12:15 7.25 4,926 5,878 INTRM1 DRILL DDRL P Drilled 9 7/8"directional hole with Geopilot from 4,926' to 5,878' MD 3,481' TVD ADT 5.26 hrs ROT 160 rpm's, WOB: 8/18 K, 743 gpm @ 2640 psi ECD 11.16 PU 160 K, SOW 125 K, ROT 142 K TRQ on/off Btm 12,000/10,500 ft-Ibs. Pumped 35 bbls high vis sweep @ 5,022' -large push of cuttings back with sweep Pumped 35 bbls high vis sweep @ 5,307' -moderate push of cuttings back with sweep Pumped 35 bbls high vis sweep @ 5,593' -moderate of cuttings back with sweep Pumped 35 bbls high vis sweep @ 5,879' -very slight push of cuttings back with swee 12:15 12:45 0.50 5,878 5,688 INTRM1 DRILL OTHR T After backreaming up and reaming down 40', hole packed off -Worked i e u to 5688' -established circulation and staged pumps up to drillin rate 12:45 13:30 0.75 5,688 5,878 INTRM1 DRILL CIRC P Circulate and clean up hole -Wash and ream from 5688' to 5,878' - 750 gpm /2570 psi / 150 rpm After 10 minutes of full pump rate hole unloaded cuttings -Very heavy for next 10 minutes of circulating time Initial ECD 11.3 -final 10.6 ppg No mud lost to hole 13:30 21:15 7.75 5,878 6,735 INTRM1 DRILL DDRL P Drilled 9 7/8"directional hole with Geopilot from 5,878' to 6,735' MD 3,856' TVD ADT 5.24 hrs ROT 160 rpm's, WOB: 8/15 K, 743 gpm @ 2720 psi ECD 10.88 PU 160 K, SOW 125 K, ROT 142 K TRO on/off Btm 12,000!10,500 ft-Ibs. Pumped 35 bbls high vis sweep as needed to clean hole. 21:15 22:00 0.75 6,735 6,735 INTRM1 DRILL CIRC NP Pumped low/high vis sweep and had packing off as sweep came out the bit. Picked up and regained circulation. Circulated and reamed hole with 750 gpm and 150 rpm. PP 2700 psi. Cutting at BU 50 to 60 more than while drillin . I'ag~ 6 of 2~t ~--- I n ~.~ ~ Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T Comment 22:00 00:00 2.00 6,735 6,892 INTRM1 DRILL DDRL P Drilled 9 7/8"directional hole with Geopilot from 6,735' to 6,892' MD 3,926' TVD ADT .95 hrs ROT 160 rpm's, WOB: 8/15 K, 743 gpm @ 2480 psi ECD 10.58 PU 162 K, SOW 138 K, ROT 151 K TRQ on/off Btm 10,500/9,500 ft-Ibs. Pumped 35 bbls high vis sweep as needed to clean hole. 5/12/2008 Drilled from 5,878' to 9,618'. 00:00 12:00 12.00 6,892 8,210 INTRMI DRILL DDRL P Drilled 9 7/8" directional hole with Geopilot from 6,892' to 8,210' MD 4,493' ND ADT 7.39 hrs ROT 160 rpm's, WOB: 10/15 K, 743 gpm @ 2360 psi ECD 10.55 PU 204 K, SOW 133 K, ROT 163 K TRO on/off Btm 15,000/13,000 ft-Ibs. 12:00 00:00 12.00 8,210 9,618 INTRM1 DRILL DDRL P Drilled 9 7/8" directional hole with Geopilot from 8,210' to 9,618' MD 5,104' TVD ADT 7.62 hrs ROT 160 rpm's, WOB: 12/20 K, 743 gpm @ 2680 psi ECD 10.77 PU 240 K, SOW 133 K, ROT 170 K TRO on/off Btm 17,500/16,500 ft-Ibs. 5/13/2008 Drilled 9 7/8" hole with Geopilot f/ 9,618' to 12,327' 00:00 12:00 12.00 9,618 10,960 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 9618' to 10,960' MD - 5686' TVD ADT - 7.91 hrs. ECD -10.91 ppg RPM 160 WOB 15/20 k GPM 750 @ 2640 psi Torque on/off btm. - 19,500/16,500 ft/Ibs Foota a drilled - 1,342' 12:00 00:00 12.00 10,960 12,327 INTRM1 DRILL DDRL P Drilled 9 7/8" hole from 10,860' to 12,327' MD/ 6,278' TVD (1,367') ADT 7.98 hrs, 15-22K wob, 160 rpm's, 177 spm, 750 gpm at 2,710 psi. Off btm torque 19K ft-Ibs, on btm 21 K ft-Ibs, rot wt 192K, up wt 257K, do wt 150K, 10.1 ppg MW, ECD 10.89 5/14/2008 Drilled 9 7/8" hole w/GP f/ 12,327' to 14,898' 00:00 12:00 12.00 12,327 13,667 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 12,327' to 13,667' MD - 6829' TVD ADT - 7.58 hrs. ECD 10.93 ppg RPM 160 WOB 15/22 k GPM 750 @ 2890 psi String wt. PU 275 SO 157 Rot 204 Torque on/off btm. - 21,500 / 18,000 ft/Ibs Foota a drilled -1340' Page 7 of 2~ Time Lo s Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 12:00 00:00 12.00 13,667 14,898 INTRM1 DRILL DDRL P Drilled 9 7/8" hole from 13,667' to 14,898' MD/7,215' TVD (1,231') ADT 7.88 hrs, 15-25K wob, 150 rpm's, 177 spm, 750 gpm at 3,450 psi. Off btm torque 17K ft-Ibs, on btm 19K ft-Ibs, rot wt 205K, up wt 275K, do wt 160K, 10.1 ppg MW, ECD 10.98 5/15/2008 Drilled 9 7/8" hole w/GP f/ 14,898 to 15,717' MD/7,372' TVD, attempted to drill deeper & was unable to drill thru hard spot at 15,717'. Backreamed out of hole to above HRZ at 13,900' w/no problems, RIH washing to btm. Pum ed hi vis swee &circ clean. S otted tube ill & be an POOH s ottin add. lube ill to 15,391'. 00:00 12:00 12.00 14,898 15,717 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ GP f/ 14,898' to 15,717' MD - 7372' TVD ADT - 7.49 hrs. ECD-10.66 ppg RPM 100/150 WOB 12/25 k GPM 750 @ 3660 psi String wt. PU 293 SO 155 Rot 207 Torque on/off btm. - 21,000 / 15,500 ft/Ibs Footage drilled - 819' Note : v ar s 12:00 15:15 3.25 15,717 15,717 INTRM1 DRILL DDRL P Cont to attempt to drill to csg pt at 15,773' and was unable to drill thru hard stringer at 15,717' called 15,717' cs t .ADT 2.06 hrs. 35K wob, 90 rpm's, 750 gpm, 3,580 psi, torque off btm 19K ft-Ibs, on btm 21 K, rot wt 207K, up wt 290K, do wt 155K, 10.1 ppg MW, ECD 10.61 . Monitored well-static. 15:15 19:00 3.75 15,717 13,900 INTRM1 DRILL REAM P Backreamed out of hole to above HRZ to 13,900', BROOH w/no problems at 130 rpm's, 600 gpm at 2,450 si. 19:00 19:30 0.50 13,900 14,735 INTRMI DRILL TRIP P RIH from 13,900' to 14735' and was takin 20-40K wt. 19:30 20:00 0.50 14,735 14,642 INTRM1 DRILL REAM P Est circ and washed and reamed spot from 14,735' to 14,642', 130 m's, 600 mat 2,540' 20:00 21:00 1.00 14,642 15,717 INTRM1 DRILL TRIP P RIH from 14,642' to 15,687' and washed and reamed last 30' to btm w/no roblems. 21:00 23:00 2.00 15,717 15,717 INTRMI DRILL CIRC P Pumped hi vis sweep and circ hole clean, (2X btms up) circ at 750 gpm, 3,710 psi and 150 rpm's, monitored well-static. 23:00 23:30 0.50 15,717 15,717 INTRM1 DRILL CIRC P Spotted csg tube pill at 9 bpm, 1,240 si and 120 m's. 23:30 00:00 0.50 15,717 15,391 INTRM1 DRILL TRIP P POOH to 15,391' spotting csg running tube pill while purring out. pumped out at 2.5 bpm at 360 psi, st wt u 285K, do wt 165K. 5/16/2008 Cont to spot tube pill to 13,900', pumped out & pulled out of hole on elevators to shoe, monitored well at shoe-static, POOH & LD BHA #2, ulled wear bushin & chan ed out to set of rams to 7 5/8". Page R of 24 • Time Logs Date From To Dur S. D th E. De th Ph e Code Subcode T Comment 00:00 02:00 2.00 15,391 13,900 INTRM1 DRILL TRIP P POOH w/pump spotting casing tube pill f/ 15,391' to 13,900' - 2.5 BPM @ 360 si 02:00 03:30 1.50 13,900 13,439 INTRM1 DRILL TRIP P Flow ck(static) attempt to POOH on TT -well swabbing -POOH w/ pump f/ 13,900' to 13,439' - 03:30 07:30 4.00 13,439 9,399 INTRM1 DRILL TRIP P POOH on TT f/ 13,439' to 9399' 07:30 08:15 0.75 9,399 9,209 INTRM1 DRILL TRIP T Backream thru tight hole f/ 9399' to 9209' - 600 gpm @ 2210 psi w/ 100 m's 08:15 09:30 1.25 9,209 8,258 INTRMI DRILL TRIP P POOH on TT f/ 9209' to 8258' 09:30 10:15 0.75 8,258 8,067 INTRM1 DRILL TRIP T Backream thru tight hole f/ 8258' to 8067' - 600 gpm @ 1880 psi w/ 100 r m's 10:15 13:00 2.75 8,067 5,402 INTRM1 DRILL TRIP P POOH on TT f/ 8067' to 5402' 13:00 13:15 0.25 5,402 5,307 INTRM1 DRILL TRIP T Backream f/5402' to 5307' 600 gpm w/ 100 m 13:15 15:00 1.75 5,307 3,309 INTRM1 DRILL TRIP P POOH on TT f/ 5307' to 3309' 15:00 17:45 2.75 3,309 271 INTRM1 DRILL TRIP P Flow ck (static) Cont POOH on TT f/ 3309' to BHA at 733', monitored well-static, LD jars and stood back HWDP. 17:45 20:30 2.75 271 0 INTRM1 DRILL PULD P LD NMFDC's and downloaded MWD, fin. LD BHA #2 and cleared ri floor. 20:30 21:15 0.75 0 0 INTRM1 DRILL PULD P Pulled long wear bushing (Dogs acked with cla 21:15 23:15 2.00 0 0 INTRM1 CASING NUND P Changed out top set of rams over to e changed over top drive saver sub to 4" XT-39. 23:15 00:00 0.75 0 0 INTRM1 CASING RURD P RU to run 7 5/8" csg and repaired thread on to ram bod . 5/17/2008 Fin. RU to run 7 5/8" csg & tested 7 5/8" csg rams 250/3,500 psi. Installed thin wear bushing. MU 7 5/8" shoe track &circ thru same, cont. to RIH with 7 5/8" csg to 13,642', circ btms up at 3,396', 6,812', 10,240' and 13,642'. 00:00 01:15 1.25 0 0 INTRM1 CASING RURD P RU to run 7 5/8" casing (while repairing ram door thread) -Test 7 5/8" i e rams to 250 & 3500 si 01:15 01:30 0.25 0 0 INTRM1 CASING OTHR P Set thin wall wear bushing for running 7 5/8" casin 01:30 02:00 0.50 0 0 INTRMI CASING RURD P Cont. RU to run 7 5/8" casing 02:00 02:15 0.25 0 0 INTRMI CASING SFTY P Held PJSM with crew on running casin 02:15 06:30 4.25 0 3,396 INTRM1 CASING RNCS P Run 7 5/8" 29.7# L-80 BTCM casino as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal w! by-pass baffle) -1 jt csg -Halliburton baffle collar - 1 jt csg (all connections made up w/ BakerLoc -filled pipe & checked floats) 76 jts csg (80 jts total to 3396' 06:30 07:00 0.50 3,396 3,396 INTRM1 CASING CIRC P Break circ & stage pump up to 6 BPM @ 400 psi - Circ casing volume + 10 bbls - PU wt 140 SO wt. 122 !'age 9 ~sf 2~ • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 10:30 3.50 3,396 6,812 INTRM1 CASING RNCS P Cont. to run 7 5/8" 29.7# L-80 BTCM f/ 3396' to 6812' 160 'ts total 10:30 12:00 1.50 6,812 6,812 INTRM1 CASING CIRC P Break circ & stage pump up to 6 BPM &circ btms up + @ 6 BPM @ 500 si - PU wt. 195 SO wt 140 12:00 16:00 4.00 6,812 10,240 INTRM1 CASING RNCS P Cont. running 7 5/8" 29.7# L-80 BTCM casing f/ 6812' to 7927' (186 jts total) Install Halliburton Stage collar (made up w/BakerLoc) - Continue running 7 5/8' 29.7# L-80 BTCM casing f/ 7927 to 10,240' (240 total 'ts in hole of 367 to run 16:00 17:45 1.75 10,240 10,240 INTRM1 CASING CIRC P Break circ & stage pump up to 6 BPM @ 460 psi &Circ btms-up +. PU wt 315K, SO wt 148K 17:45 21:45 4.00 10,240 13,642 INTRM1 CASING RNCS P Cont. running 7 5/8" 29.7# L-80 BTCM casing f/ 10,240' to 13,642' 320 total 'ts in hole of 367 to run . 21:45 00:00 2.25 13,642 13,642 INTRM1 CASING CIRC P Circ btms up + staging pump rate up to 6.5 bpm at 650 psi, PU wt 410K, SO wt 160K 5/18/2008 Fin RIH w!7 5/8" csg & landed same at 15,702'. Circ & cond. mud then cmt'd csg in 2 stages w/no problems (did not reciprocate csg). Rd cmt equip & installed 7 5/8" packoff & tested same. Changed out 7 5/8" csg rams back to VBR's & be an LD 5" DP out of the derrick thru the mousehole. 00:00 02:15 2.25 13,642 15,702 INTRMI CASING RNCS P Cont. RIH with 7 5/8" csg f/13,642', MU FMC fluted hanger and landed csg w/shoe @ 15,702' - FC @ 15,613' -Baffle collar @ 15,669' - Stage collar @ 7772' - SO wt 150K Ran a total of 367 jts and 1-12' pup of 7 5/8", 29.7#, L-80, BTCM csg, total including float equip and hanger 15,668.67' 02:15 02:45 0.50 15,702 15,702 INTRM1 CASING RURD P RD Franks fill up tool, blow down top drive and MU Dowell cement head. 02:45 04:45 2.00 15,702 15,702 INTRMI CEMEN' CIRC P Circ and cond. mud for cementing staged pump rate up from 2.5 bpm at 440 psi to 7 bpm at 670 psi, circ 10.2 ppg MW in, held PJSM while circ hole and did not reci rocate i e. Page 10 0~ 24 • Time Lis Date From To Dur S De th E. De th Ph e Code Subcode T Comment 04:45 08:00 3.25 15,702 15,702 INTRM1 CEMEN" DISP P Cemented 1st sta a as follows dropped wiper dart then pumped 10 bbls CW 100, pressure tested lines to 4,000 psi, loaded displacement dart and fin. pumping 30 bbls (40 total) of CW 100 at 8.3 ppg, ave 4 bpm at 415 psi., then pumped 40 bbls of Mud Push at 10.5 ppg, 4 bpm and 400 psi. Mixed and pumped 112 bbls (176 sxs) of LiteCrete lead cmt at 11.0 ppg and 3.35 yield wladditives, ave 6.2 bpm, ICP 590 psi, FCP 435 psi., followed with 36.6 bbls (164 sxs of class "G" tail cmt at 15.8 ppg and 1.16 yield w/additives, ave 4.5 bpm at 210 psi. Dropped displacement dart and Dowell pumped 20 bbls water then turned over to rig and rig fin. displacing cmt with 695 bbls of 10.2 ppg LSND mud, ave. 7 bpm, ICP 400 psi, max press. 650 psi, with 20 bbls to go slowed to 3.5 bpm at 390 psi and bumped plug to 900 psi. CIP 07:50 hr~ had full returns checked floats and held. Calc TOC 13,300'. 08:00 09:00 1.00 15,702 15,702 INTRM1 CEMEN" CIRC P Loaded 2nd stage closing plug then pressured up to 3,200 psi opening the HES cementer, circ btms up at 7 bpm at 330 psi. 10.2 ppg MW in and out. 09:00 10:30 1.50 15,702 15,702 INTRM1 CEMEN" DISP P Cemented 2nd stage as follows, pumped 20 bbls of CW 100 at an ave 4 bpm at 180 psi and followed with 30 bbls of MudPush at 10.5 ppg, 4.5 bpm at 200 psi. Then mixed and pumped 58.5 bbls, (274 sxs) of class "G" tail cmt at 15.8 , 1.17 field w/additives, ave 4.5 bpm, ICP 190 psi, FCP 130 psi. Dropped closing plug and Dowell pumped 20 bbls water then the rig displaced cement with 337 bbls of 10.2 ppg mud, ave 7 bpm, ICP 200 psi, FCP 380 psi, with 20 bbls left in displacement slowed to 3.5 bpm at 240 psi, bumped plug to 1,700 psi and closed HES cementer. CIP at 10:20 hrs, bled off press. and tool was closed, had full returns throught the job and talc: TOC is at 6,719'. 10:30 11:30 1.00 15,702 15,702 INTRM1 CEMEN" RURD P Blow down lines - RD cmt lines & cmt head - LD landin 't. 11:30 12:00 0.50 15,702 15,702 INTRM1 CEMEN" OTHR P Drain stack -Pull thin wall wear bushin 12:00 12:30 0.50 15,702 0 INTRM1 CASING NUND P Set packoff and tested 5000 psi. OK. Page 11 of 24, • Time Logs Date From To Dur S. De th E. De th Ph se Code Subcode T Comment 12:30 14:00 1.50 0 0 INTRM1 CASING NUND P Chan ed 7 5/8" rams to VBR. RD casin tools. 14:00 00:00 10.00 0 0 INTRM1 DRILL PULD P PJSM and laid down 5" DP from derrick via mousehole. 5/19/2008 Finish LD 5" DP - RU & Tested ROPE 250/3,500 psi, Chuck Scheve W/AOGCC waived witnessing of test - MU BHA #3 -RIH PU 4" DP to 7,700'-Slip & cut drlg line -Test csg above stage tool 3,500 psi fl10 min - Drilled out sta a tool 7,772'-7,775', washin down at 7,795'. 00:00 04:45 4.75 0 0 INTRM1 DRILL PULD P Finish laying down 5" DP f/ derrick via mouse hole LD 486 'ts total 04:45 10:30 5.75 0 0 INTRM1 WELCTL BOPE P RU & Test BOPE - Annular to 250 & 2500 psi -Pipe rams, choke & kill line valves, choke manifold valves, TD IBOP valves, floor safeyt & dart valves, blind rams to 250 & 3500 psi - performed accumulcator closure test -tested VBR's with 3 1/2" & 4 1/2" test jts. for liner & tbg runs - RD. NOTE: Chuck Scheve W/AOGCC waived witnessin of the test. 10:30 10:45 0.25 0 0 INTRM1 DRILL OTHR P Install wear bushing 10:45 11:30 0.75 0 0 INTRMI DRILL PULD P PU & std back 5 stds of 4" DP 11:30 12:30 1.00 0 287 INTRM1 DRILL PULD P MU BHA #3 (clean out assembly) bit -BS-stab-3NMDC's-XO-3jts HWDP - 'ars - 2 'ts. HWDP to 287' 12:30 18:15 5.75 287 7,700 INTRM1 DRILL TRIP P RIH w/ BHA # 3 f/ 287' -picking up 4" DP f/ i e shed RIH to 7,700' 18:15 18:45 0.50 7,700 7,700 INTRM1 DRILL CIRC P Circ a DP volume at 6 bpm, 950 psi and 60 r m's 18:45 20:15 1.50 7,700 7,700 INTRM1 RIGMNT SVRG P Held PJSM then slip and cut 120' of drlg line then serviced top drive. Tested 7 5/8" csg above stage tool to 3,500 si for 10 min and ck'd ok. 20:15 00:00 3.75 7,700 7,795 INTRMI CEMEN" DRLG P Washed down from 7,700' and tagged plug above HES cementer/stage collar, drilled out stage collar from 7,772' to 7,775' and cont. to wash down to 7,795'. 5/20/2008 Wash /Ream & RIH f/ 7795' - 15525' MD; Pulled Up t/ 15515' and Tested 7 5/8" Casing to 3500 psi f/ 30 Minutes (Good); Drill Float Collar & 8' of New Hole f/ 15515' - 15725' MD; Circulated Bottoms Up, Observed Well for Flow Static ,and Pum ed /Pulled Out-of-Hole f/ 15725' -12760' MD 00:00 01:00 1.00 7,795 7,700 INTRM1 DRILL REAM P Cont. was & ream f/ 7795' to 7986' w/300 gpm @ 1130 psi - 100 rpm's PU wt. 185 SO wt. 110 Rot wt. 135 Pull & std back 3 stds DP to 7700' - Blowdown TD 01:00 02:15 1.25 7,700 8,747 INTRMI DRILL TRIP P RIH f/ 7700' to 8747' -picking up 4" DP f/ pipe shed Took wt. 8747' 02:15 03:30 1.25 8,747 8,747 INTRM1 DRILL REAM T Wash & ream f/ 8747' to 9030' w/ stds f/derrick w/ 7 bbls/min @ 1230 psi w/ 110 rpm's PU wt. 195 SO wt. 110 Rot wt. 135 - POOH & std back 3 stds -Blow down TD 4~age 7 2 ~~f ~~€ J l J Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 07:00 3.50 8,747 12,940 INTRM1 DRILL TRIP P Cont. RIH f/ 8747' to 12,940' picking up 4" DP f/ pipe shed -took wt. @ 12,940' 07:00 07:30 0.50 12,940 12,951 INTRM1 DRILL REAM T Wash & ream f/ 12,855' to 12,951' - Blow down TD 07:30 10:15 2.75 12,951 15,332 INTRM1 DRILL TRIP P Cont. RIH f/ 12,951' to 15,332' - picking up 4" DP f/ pipe shed -all DP icked u for this run 10:15 10:30 0.25 15,332 15,525 INTRM1 DRILL TRIP P RIH f/ 15,332' w/ DP f/ derrick to 15 525' to ed to of cmt 10:30 12:00 1.50 15,525 15,515 INTRM1 DRILL CIRC P Break circ & circ for casing test - Pull up to 15,515' - RU for casing test 12:00 13:00 1.00 15,515 15,515 INTRM1 DRILL OTHR P mins Good Test - RD 13:00 17:00 4.00 15,515 15,725 INTRM1 DRILL DRLG P Clean out shoe track -Drilled baffle collar @ 15,569', cmt to FC @ 15,613' -drilled FC to 15614' -clean out cmt to top of FS @ 15700' - Drilled out FS to 15,702' -Clean out rat hole to 15,717' -Drilled 8' of New Hole f/ 15515' - 15725' MD; 325 GPM @ 2200 psi; 100 RPM - Had no problem drilling through hard spot @ 15,717' 17:00 18:15 1.25 15,725 15,725 INTRM1 DRILL CIRC P CBU; 325 GPM @ 2300 psi; Rot / Reci Pie 100 RPM 18:15 18:30 0.25 15,725 15,725 INTRM1 DRILL OWFF P Flow check -well static 18:30 20:00 1.50 15,725 14,673 INTRM1 DRILL TRIP P Pump Out of Hole f/ 15725' - 14673' MD 20:00 20:15 0.25 14,673 14,673 INTRM1 DRILL OWFF P Flow check (Static); Blow Down Top Drive 20:15 22:15 2.00 14,673 13,620 INTRMI DRILL TRIP P POOH on TT f! 14673' - 13620' MD; Pum ed D Job 13716' MD 22:15 22:45 0.50 13,620 13,620 INTRM1 RIGMNT SVRG P Rig Service 22:45 00:00 1.25 13,620 12,760 INTRMI DRILL TRIP P POOH f/ 13620' - 12760' MD; P/U 270, S/O 125 5/21 /2008 Continued to POOH w/ Clean out BHA and Lay Down Same; P/U BHA #4 6 3/4" Bit, Geo-Pilot, MWD, Geo Tap, Non-Magnetic Float Sub, Non-Magnetic Flexible Drill Collars, Hevi-Wate Drill Pipe, and Drilling Jars; RIH f/ 382' - 15614' MD w/ 261 Jts (87 Stds) of 4" DP f! Pipe Shed then 73 Stds of 4" DP f/ the Derrick Filling Pipe Eve 20 Stands; Cut & Sli 60' 8 Wra s of 1 3/8" Dia. Drill Line 00:00 08:30 8.50 12,760 287 INTRM1 DRILL TRIP P Cont. POOH on TT f/ 12760' to 287' HWDP -Flow ck -static 08:30 09:15 0.75 287 0 INTRM1 DRILL PULD P SB HWDP & Jars - LD XO - PU & break bit - LD stab & std back NMDC's 09:15 11:30 2.25 0 98 INTRMI DRILL PULD P MU BHA #4 - GeoPilot -MWD - GeoTap - Up load MWD -Pressure test Geos an 11:30 12:00 0.50 98 382 INTRM1 DRILL PULD P MU NM float sub - NM flex DC's - HWDP & Jars -shallow test MWD- MU 1 std HWDP 12:00 19:30 7.50 382 8,671 INTRM1 DRILL TRIP P RIH w/ BHA #4 f/ 382' to 8671' MD - ickin u 4" DP f/ i e shed large 13 ~sf Z~ • Time Logs D e From To Dur S. De th E. De th Phase Code Subcode T Comment 19:30 23:00 3.50 8,671 15,614 INTRM1 DRILL TRIP P RIH w/ BHA #4 f/ 8671' - 15614' MD w/ 4" DP f/ Derrick; P/U 290, S/O 114 23:00 23:15 0.25 15,614 15,614 INTRM1 RIGMNT SFTY P PJSM Cut & Slip Drill Line 23:15 00:00 0.75 15,614 15,614 INTRM1 RIGMNT SVRG P Cut & Slip 60' (8 Wraps) of 1 3/8" Dia Drill Line 5/22/2008 Finish C&S DL - RIH to 15,725' - Drill to 15,737' -Girt Btms up -Perform FIT to 12.5 ppg EMW - GP failure - POOH to Replace Geo-Pilot, NM GP Flex Collar, & DM; P/U BHA and Shallow Test (Successful); RIH t/ 2761' MD 00:00 00:45 0.75 15,614 15,614 INTRM1 RIGMNT SVRG P Finish cut & slip drill line 00:45 01:15 0.50 15,614 15,725 INTRM1 DRILL REAM P Break circ -Wash & ream f/ 15,614' to 15,725' breakin in GP bearin s 01:15 01:30 0.25 15,725 15,737 INTRM1 DRILL DDRL P /4" holl<e f/ 15.725' to 15.737'. MD 7375' TVD ADT - .29 hrs. WOB 12 k RPM 80 GPM 300 @ 3350 si 01:30 03:00 1.50 15,737 15,614 INTRM1 DRILL CIRC P Circ btms up for FIT @ 300 gpm - 3350 psi w/ 80 rpm Pull u to 15,614' 03:00 04:30 1.50 15,614 15,614 INTRM1 DRILL FIT P RU & erform FIT to 12.5 qpq EMW- w/ 880 psi surface pressure w/ 10.2 mud 7370 ' TVD - RD 04:30 05:00 0.50 15,614 15,614 PROD1 DRILL OTHR T GeoPilot not responding to down link -Trouble shoot GP -Unsuccessful 05:00 07:15 2.25 15,614 14,663 PROD1 DRILL TRIP T POOH w/ pump f/ 15,614' to 14,663' w/ 3.5 bbls/min @ 930 psi -Trouble shoot GeoPilot @ 14,663' - Unsucessful Blwo down TD -Flow ck -Static 07:15 12:00 4.75 14,663 9,812 PROD1 DRILL TRIP T POOH f/ 14,663' - 9812' MD; P/U 235, S/O 118 12:00 18:00 6.00 9,812 382 PROD1 DRILL TRIP T POOH f! 9812' - 382' MD; P/U 100; S/O 100 18:00 19:00 1.00 382 102 PROD1 DRILL PULD T Stand Back HWDP, Jars, NMFDC's 19:00 19:30 0.50 102 102 PROD1 DRILL DHEQ T Plug In, Download, & Turn Off MWD 19:30 20:30 1.00 102 0 PROD1 DRILL PULD T UD & Replace DM, NM GP Flex, Geo-Pilot for No Communication 20:30 21:15 0.75 0 0 PROD1 DRILL PULD T P/U & M/U Geo-Pilot, NM GP Flex, DM, Smat Stab, Gamma, Geo-Tap / PWD, TM 21:15 21:45 0.50 100 100 PROD1 DRILL DHEQ T Plug In & Turn On MWD 21:45 22:30 0.75 100 290 PROD1 DRILL PULD T P/U Float Sub, 3 - NMFDC's, XO, 3 - HWDP; Shallow Test MWD and Geo-Pilot 22:30 00:00 1.50 290 2,761 PROD1 DRILL TRIP T P/U Jars, 2 - HWDP, and RIH f/ 290' - 2761' MD; Filling Pipe Every 20 Stds 2,761 PROD1 DRILL Paga-14 cat 2AI 1. J J Time Logs Date From To Dur S. De th E De th Ph e Code Subcode T Comment 5/23/2008 24 hr summary RIH f/ 2761' to 15,708' -Acquire detection f/ MWD -Change over to 9.8 ppg FloPro while drilling f/ 15,737' to 15,803' -Obtain SPR -monitor well -Static -Drill 6 3/4" horizontal section w/ GP f/ 15,803' to 17020' MD; Take Geo-Tap Surveys @ Sensor Depths 15895' (EMW 9.61) & 16100' (EMW 9.65); Raised MW f/ 9.8 PPG to 10.0 PPG; Took Geo-Tap Survey @ 16651' MD, EMW Results Were Invalid Due to Low Formation Permiabili 00:00 04:45 4.75 2,761 15,708 PROD1 DRILL TRIP T Cont. RIH w/ BHA #5 f/ 2761' to 15,708' - fillin ie eve 20 stds. 04:45 05:30 0.75 15,708 15,708 PROD1 DRILL CIRC T Establish circ & squire detection f/ MWD & GP 05:30 07:45 2.25 15,708 15,803 PROD1 DRILL DDRL P Pump Safe Surf-O spacer & Hi vis push pill (w/ FloPro @ 9.8 ppg displace well f/ 10.2 ppg LSND to 9.8 ppg FloPro -Pumped DP volume + 10 bbls -Drilled 6 3/4" hole f/ 15,737' to 15,803' -Continue Circ & rotate until FloPro returns to surface 07:45 08:00 0.25 15,803 15,803 PROD1 DRILL OTHR P Obtain Slow pump rates -Monitor well -Static 08:00 12:00 4.00 15,803 16,030 PROD1 DRILL DDRL P Drilled 6 3/4" Horizontal section w! GP f/ 15,803' to 16,030' MD 7403' TVD ECD - 10.94 ppg ADT - 2.84 hrs RPM 120 WOB 10/17 k GPM 300 @ 3110 psi String wt. PU 210 SO 140 Rot - 174 Torque on/off btm. -12,000!10,000 ft/Ibs Note -Took Geo Tap measurement 15 890' - 9.61 EMW 12:00 18:00 6.00 16,030 16,590 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal sectioon w/ GP f/ 16030' - 16590' MD; 71 SPM @ 3220 psi; WOB 15, RPM 120, Torque On 13 /Off 11; P/U 210, S/O 145, Rot 175; ECD = 11.09; ADT = 4.79 GeoTa Taken 16,100' MD, EMW = 9.6 Raised MW f/ 9.8 to 10.0 PPG 18:00 00:00 6.00 16,590 17,020 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section W GP f/ 16590' - 17020' MD; 71 SPM @ 3380 psi; WOB 16, RPM 120, Torque On 13 /Off 11; P/U 212, S/O 142, Rot 174; ECD = 11.22; ADT = 3.92 Geo Tap Taken @ 16,651' MD (Sensor Depth), EMW = 10.73; Formation "Low Permiability" EMW Invalid 5/24/2008 Drilled 6 3/4" horizontal section w/GP f/ 17,020' to 18,980' Obtained Geo Tap readings @ 17,126' - 17,600' - 18,078' - 18,556' E~~g~ 15 of 24 ~ Time Lo s Date From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 12:00 12.00 17,020 18,073 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 17,020' to 18,073' MD - 7400' ND ADT - 8.06 hrs. ECD -11.6 ppg RPM 120 WOB 12 k GPM - 300 to 280 @ 3200 psi String wt. PU 215 SO 135 Rot 175 Torque on/off btm. -14,000/12,000 ft/Ibs Obtained Geo Tap samples @ 17,198' - 10.01 ppg EMW & 17,600' -10.38 ppg EMW Flow checks have been static w/ some bubbling of mud observed Bumped mud wt f/ 10.1 ppg to 10.4 12:00 00:00 12.00 18,073 19,025 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 18,073' to 18,980' MD - 7386' ND ADT - 8.07 hrs. ECD - 11.87 ppg RPM 120 WOB 14-16 k GPM - 286 @ 3300 psi String wt. PU 227 SO 128 Rot 173 Torque on/off btm. -14,000/11,000 ft/Ibs Obtained Geo Tap samples @ 18,078' - 10.52 ppg EMW & 18,556' - 10.49 ppg EMW Flow checks have been static w/ some bubbling of mud observed MW -10.4 5/25/2008 Drilled 6 3/4" horizontal section w/ GP f/ 18,980' to 20950' -Obtained Geo Tap readings @ 19,035' - 19,512' - 19,992' & 20,4770' 00:00 12:00 12.00 18,980 19,955 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 18,980' to 19,955' MD 7374' ND ADT - 8.48 hrs. ECD - 11.8 ppg w/ 10.4 ppg mud wt. RPM 120 WOB 15 k GPM 286 @ 3450 psi String wt. PU 225 SO 123 Rot 173 torque on/off btm. -14,500/12,000 ft/Ibs Obtained Geo Tap data @ 19,035' - 10.57 ppg EMW & 19,513' - 10.80 ppg EMW All connections have been static - w/ fluid level 2 to 6 inches below flow line & mud bubblling -monitored for gas at possum belly - no reading on LEL meter Page ?~ ~f 2d • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 12:00 00:00 12.00 19,955 20,950 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 19,955' to 20,950' MD 7364' TVD ADT - 8.63 hrs ECD-12.02 ppg RPM 120 WOB 13/14 k GPM 280 @ 3630 psi String wt. PU 235 SO 115 Rot 175 Torque on/off btm. -15,500/13,000 ft/Ibs Obtained Geo Tap readings @ 19,992' - 10.6 ppg EMW - 20,470' - 10.64 ppg EMW Note -Connections have been static with mud bubbling -Monitored for gas at possum belly - no indication - monitored for gas at mud buckett line - High LEL readings -Bump mud wt. to 10.6 5/26/2008 Drilled 6 3/4" Horizontal Section f/ 20,950' - 22,600' MD; Obtained Geo-Tap Readings @ 20,949' - (10.68); 21,425' - (10.66); 21,904' - (10.65); & 23,379' - (10.5) Bum ed Mud Wei ht f/ 10.6 to 10.8; Connections Static but Bubblin 00:00 12:00 12.00 20,950 21,817 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 20,950' to 21,817' MD - 7362' TVD ADT - 8.42 hrs. ECD -12.2 ppg @ 10.6 ppg mud wt. RPM - 120 WOB - 12 k GPM 270 @ 3660 psi String wt. PU 230 SO 120 Rot 173 Torque on/off btm. -17,000/15,000 ft/Ibs Obtained Geo Tap reading @ 20,949' - 10.68 ppg EMW & 21,425' -10.66 ppg EMW All connections were static w/mud bubbllin Page 1T of 2A Time Logs ~ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 00:00 12.00 21,817 22,600 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 21,817' to 22,600' MD - 7360' TVD ADT - 8.43 hrs. ECD - 12.5 ppg @ 10.8 ppg mud wt. RPM -120 WOB - 12 k GPM 270 @ 3720 psi String wt. PU 250 SO N/A Rot 173 Torque on/off btm. - 21,000/16,500 fUlbs Obtained Geo Tap reading @ 21,904' - 10.65 ppg EMW & 22,379 - 10.50 ppg EMW All connections were static w/mud bubbltin 5/27/2008 Drilled Horizontal Section f/ 22,600' - 23, 539; MD; Hole Started Taking Mud @ 23,539' MD at 63 SPM Lost Mud at 140 BPH; Slowed Pump Rates to 30 SPM Losses Dropped to 50 BPH; Pumped Two LCM Sweeps and Chekced Quantity of Flow vs. Time -Flow Reduced f/ 2.6 BPM to .55 BPM w/ a Total of 22.25 Bbls Returned; POOH U 23,156' MD; Increased MW f/ 10.8 to 11.0 PPG; Hole Took an Average of 50 BPH for Rest of Tour; Total Losses = 325 Bbl 00:00 12:00 12.00 22,600 23,315 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 22,600' to 23,315' MD - 7361' TVD ADT-9.13 hrs. ECD-12.3-12.5 ppg @ 10.8 ppg mud wt. RPM - 120 WOB - 12 k GPM 265 @ 3650 psi String wt. PU 245 SO N/A Rot 170 Torque on/off btm. -19,000/15,000 fUlbs Obtained Geo Tap reading @ 22,860' - 10.45 ppg All connections were static -some w/ mud bubbltin 12:00 15:30 3.50 23,315 23,539 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 22,315' to 23,539' MD - 7355' TVD ADT - 2.88 hrs. ECD - 12.6 - 12.5 ppg @ 10.8 ppg mud wt. RPM - 120 WOB -14 k GPM 265 @ 3700 psi String wt. PU 250 SO N/A Rot 169 Torque on/off btm. - 18,500/17,500fUlbs Obtained Geo Tap reading @ 23,341 - Test Invalid X 2 All connections were static -some w/ mud bubbltin t~a3~~i ~ 4 ~~ 4~ l J Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T Comment 15:30 00:00 8.50 23,539 23,156 PROD1 DRILL CIRC T Mud Loss 23 539' MD 140 - 60 BPH; Slowed Pump Rate U 3 BPM Losses Dropped to 50 BPH; Pumped Two LCM Pills 30 and 35 BBLs Each Composed of 10 PPB Safe Carb 250 and 10 PPB Dyna Red Medium; Reamed Out-of--Hole U 23,156' MD Pulling 1 Stand e/ Two Hours After LCM Pill @ Bit; Weight Up Mud System f/ 10.8 -11.0 PPG; P/U 250, S/O 100, Rot 175 @ 23,156' MD Checked Rate of Flow Back w/ Pumps Off; For First 5 Minutes Bled Back 13 Bbls @ 2.6 BPM -- For Second Five Minutes Bled Back 6.5 Bbls @ 1.3 BPM -Final Five Minutes Bled Back 2.75 Bbls @ .55 BPM; Total Volume Bled Back = 22.25 Bbls; Flow Line Percent Dropped f/ 21 % to 1 % During Test **Lost 325 bbls of mud to hol 5/28/2008 Continued to Circulate and Weight Up Mud System to 11.0 PPG; Back Reamed Out-of-Hole f/ 23,156' - 15,708' MD; Circulate, Condition & Weight Up Mud System U 11.3 PPG; Conduct Well Bore Exhale Test; Bled Back 25.05 Bbls Durin Test; Total Mud Lsot to Hole for Past 24 Hrs = 389 Bbls 00:00 06:15 6.25 23,156 22,995 PROD1 DRILL CIRC T Continue to circulate and wt. up mud to 11.0 ppg - 3 bpm / 1420 psi / 60 rpm -Set back one stand / 30 minutes from 23,156' to 22,295' - mud wt. in & out 11.0 06:15 12:00 5.75 22,995 20,000 PROD1 DRILL TRIP P Backream from 22,295' to 20,000' - 4 bpm / 1680 psi / 60 rpm Mud wt. out 11.0 - 10.6 ppg - maintain mud wt. in at 11.0 ppg PUW 240 K SOW 140 K Rt.Wt. 175 k Rot Torque 16 K @ 20,000' **Lost 109 bbls of mud in last 12 hours 12:00 17:45 5.75 20,000 15,708 PROD1 DRILL TRIP P Continue to BROOH f/ 20,000' - 15,708' MD; 40 SPM 1660 Psi 17:45 21:45 4.00 15,708 15,708 PROD1 WELCTL COND T Circ & Condition Mud; Weight Up S stem f/ 11.0 - 11.3 PPG Par„ 1'i of 24 Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 21:45 00:00 2.25 15,708 15,708 PROD1 WELCTL OTHR T Conduct Exhale Test as Follows: Shut Down Pumps, Monitor Flow, and R/U Pressure Gauges to DP and Choke Manifold; Monitored Well f/ 10 Minutes Flow Decreased f/ 18 % - 11 %, Rate Decreased f/ 90 BPH - 45 BPH; Over 10 Minute Observation Well Bled Back 13.5 Bbls ""` Well Not Flowing Through Choke"" Shut Well In and Observed Pressures Build and Stabilize as Follows: SIDPP Increased f/ 160 - 184 Psi; SICP Increased f/ 172 -176 Psi Bled Annulus Through Choke f/ 10 minutes as Follows: SIDPP Decreased f/ 184 - 82 Psi, SICP Dropped to 0 Psi; Flow Rate Decreased f/ 48 - 24 BPH; Total Mud Bled Back = 6.3 Bbls Shut Well In and Observed Pressures Build and Stabilize as Follows: SIDPP Increased f/ 96 - 105 Psi; SICP Increased f/ 133 -146 Psi Bled Annulus Trough Choke f/ 10 Minutes as Follows: SIDPP Decreased f/ 105 - 26 Psi; SICP Dropped to 0 Psi; Flow Rate Decreased f/ 45 -15 BPH; Total Mud Bled Back = 5.25 Bbl Shut Well In and Observed Pressures Build and Stabilize as Follows: SIDPP Increased f/ 20 - 22 Psi; SICP Increased f/ 84 - 100 Psi Opened Choke and Drill Pipe & Monitored Well; Flow Decreased f/ 8.4 - 3.24 BPH in 1 hr Total Mud Lost to Period = 280 Bbls Total Mud Lost to Hole f/ 24 Hr Period = 389 Bbls 5/29/2008 Continue to Monitor Well (Well Static in 80 Minutes); Pumped Out-of--Hole f/ 15,708' - 13,331' MD @ 2 BPM / 600 psi; Change 4" XT Saver Sub /Cut & Slip 60' of 1 3/8" Drill Line -Monitored Well Throughout (Static); Pulled Out-of-Hole on Elevators f/ 13,331' - 382' MD; Monitored Displacement Troughout Trip via Trip Tank & Flow Check (Static); Layed Down BHA per Sperry Rep; Tested Upper Variable Pipe Rams t/ 250/3500 for 5 Minutes (Good); R/U and Run 4 1/2" Liner per Detail U 3945' MD Total Mud Lost to Hole in 24 hr Period = 56 bbls Page 2p of 24 Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 00:45 0.75 15,708 15,708 PROD1 WELCTL OWFF T Continue to monitor breathing -well static in 1 hr and 20 minutes -blow down choke lines 00:45 04:15 3.50 15,708 13,331 PROD1 DRILL TRIP P POOH with pumps from 15,708' to 13,331' - 2 b m / 600 si 04:15 06:45 2.50 13,331 13,331 PROD1 RIGMNT SVRG P PJSM -change out 4" XT saver sub on top drive -PJSM -Slip and cut drilling line -Service top drive and drawworks -monitor well on TT - Static 06:45 12:00 5.25 13,331 7,624 PROD1 DRILL TRIP P POOH on TT from 13,331' to 7,624' - Flow check well, static 12:00 16:00 4.00 7,624 380 PROD1 DRILL TRIP P Continue to POOH on TT from 7,624' to 380' -flow checked well @ 1900' & 380' -static 16:00 18:45 2.75 380 0 PROD1 DRILL PULD P POOH -stand back hwdp & jars - Lay down NMFC's -Down load LWD - La down remainder of BHA 18:45 19:45 1.00 0 0 COMPZ WELCTL BOPE P Pull Wear Bushing P/U 4" Test Jt. and Test Upper Variable Pipe Rams to 250 / 3500 si f/ 5 Minutes Good 19:45 20:30 0.75 0 0 COMPZ RPCOM RURD P R/U to Run 4 1/2" Liner; P/U Perf Pu sand Install Wear Bushin 20:30 20:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM w/Crew, Company Rep, and BOT on Runnin 4 1/2" Liner 20:45 00:00 3.25 0 3,945 COMPZ RPCOM PULD P P/U 4 1/2" Liner and Perf Pus er Liner Detail and RIH f/ 0' - 3,945' MD P/U 105, S/O 95 @ 3945' MD Total Mud Lost to Hole in Past 24 Hrs = 56 Bbls 5/3 012 0 0 8 RIH w/ 4 1/2" Liner per Detail f/ 3,945' - 21,202' MD; Liner Differentially Stuck after 21,202' Connection; Worked Stuck Pipe and Recieved Okay to Set Hanger High; Dropped Ball and Set Hanger at 12,862' MD (Top); Observed Well for Flow @ 12,862' MD -- Still Breating -- Flow Rate Decreased f/ 2.28 - 0.93 BPH in 17 Minutes; Pumped 20 Stands Out-of-Hole f/ 12,862' - 11,056' MD; Observed Well for Flow -Still Breathing -- Flow Rate Decreased f/ 3.96 - .86 BPH in 5 Minutes; POOH on Elevators f/ 11,056' - 8,674' MD; Observed Well for Flow 8,674' MD Static 00:00 04:45 4.75 3,945 8,340 COMPZ RPCOM PULD P Continue to P/U 4 1/2" Liner and Perf Pups per Liner Detail and RIH f/3,945' MD to 8,305' (190 joints - 35 pert pups total) MU Baker Flex Lock hanger assembly (Liner OA= 8340.39') Fill liner Tie back With "Palmix" -allow 30 minutes set uptime - P/U 140 K, S/O 105 K 04:45 12:15 7.50 8,340 21,202 COMPZ RPCOM RCST P RIH with Liner below 4" drill pipe from 8,340' to 21,202' PUW 270K SOW 108K -after connection @ 21,202' - unable to move i e. 12:15 16:45 4.50 21,202 21,202 COMPZ RPCOM OTHR T Work stuck i e 435K - 80K - Received OK to set han er hi h 16:45 18:45 2.00 21,202 12,862 COMPZ RPCOM OTHR P Drop Ball & Set Hanger; Ball On Seat 983 Strokes, Pressure Up to 3500 psi, Released Hanger To of Liner 12 862' MD Parse* 2'i ref 24 Time Logs Date From To Dur S D th E. De th Ph e Code Subcode T Comment 18:45 19:00 0.25 12,862 12,862 COMPZ RPCOM OWFF P OWFF; Well Bore Still Breating; Flow Dropped f/ 2.28 - 0.93 BPH in 17 Minutes 19:00 21:15 2.25 12,862 11,056 COMPZ RPCOM TRIP P Pump Out-of-Hole f/ 12,862' -11,056' MD; 2 BPM 550 si 21:15 21:30 0.25 11,056 11,056 COMPZ RPCOM OWFF P OWFF; Still Breathing; Flow Rate Decreased f/ 3.96 - .86 BPH in 5 Minutes 21:30 23:45 2.25 11,056 8,674 COMPZ RPCOM TRIP P POOH on Elevators f/ 11,056' - 8,674' MD (25 Stds); Hole Fill 15% More than Calculated 23:45 00:00 0.25 8,674 8,674 COMPZ RPCOM OWFF P OWFF; Hole Static Mud Lost in Past 24 Hrs = 30 Bbls 5/31 /2008 Continued Pulling 4" DP and Baker Oil Tools Liner Setting Tools f/ 8674' -Sfc; Changed Wear Ring; Rigged Up to Run 3 1/2" Completion Tubing; Ran 3 1/2" Completion String f/ Sfc - 10703' MD as Follows: WLEG, 3 12P' 12.6# Pup Jt, Fluted No-Go Sub, XO - EUE X IBT, 1 Jt Tubing, HES "XN" Nipple, 2 Jts Tubing, BOT 7 518" Premier Packer, 1 Jt Tubing, CAMCO KBMG GLM w/ DK2 Shear Valve, 60 Jts Tubing, CAMCO KBMG GLM w/ Dummy, 163 Jts Tubing, CAMCO KBMG GLM w/ Dummy, 110 Jts Tubing, CAMCO TRMAXX-5E SSSV, Control Line & Clamps "`Lost High Line Power for 3 Hours; Ran on One Rig Generator, and Camp Generator for 3 Hours'"'"' Mud Lost to Hole in Past 24 Hrs = 67 Bbls Total Mud Lost to Hole = 867 Bbls 00:00 04:45 4.75 8,674 0 COMPZ RPCOM TRIP P POOH w/ 4" DP and BOT Hanger Settin Tool t/ Surface 04:45 05:15 0.50 0 0 COMPZ RPCOM PULD P UD BOT Liner Setting String 05:15 05:30 0.25 0 0 COMPZ RPCOM OTHR P Pull Wear Bushing & Set Com letion Wear Rin 05:30 06:15 0.75 0 0 COMPZ RPCOM RURD P R/D 4 1/2" Liner Running Tools and R/U to Run 3 1/2" Tubing; Clear Rig Floor 06:15 06:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM on Running 31/2" Liner w/ Rig Crew, Doyon Casing Crew, BOT Rep & CPAI Re 06:30 17:15 10.75 0 8,454 COMPZ RPCOM RCST P Run 3 1/2" Completion String f/ 0' z. 8454' MD as Follows: WLEG, 3 12P' 12.6# Pup Jt, Fluted No-Go Sub, XO - EUE X IBT, 1 Jt Tubing, HES "XN" Nipple, 2 Jts Tubing, BOT 7 5/8" Premier Packer, 1 Jt Tubing, CAMCO KBMG GLM wl DK2 Shear Valve, 60 Jts Tubing, CAMCO KBMG GLM w/ Dummy, 163 JTs Tubing, CAMCO KBMG GLM w/ Dummy & 39 Jts Tubing P/U 85, S!O 85 3404' MD 17:15 20:15 3.00 8,454 8,454 COMPZ RPCOM WOEQ N High Line Power Down f/ 3 Hrs; Rig on 1 Generator f/ 3 hrs and Camp on 1 Generator f/ 3 Hrs; Unable to Continue w/ Ops Per Air Permitting Constraints Fage 2c of 24 Time Logs Date From To Dur 5 De th E. De th Ph e Code Subcode T Comment 20:15 22:30 2.25 8,454 10,689 COMPZ RPCOM RCST P Continue to Run 3 1/2" Completion f/ 8454' - 10,689' MD as Follows: 71 Jts Tubing P/U 135, S/O 95 22:30 23:30 1.00 10,689 10,689 COMPZ RPCOM RURD P R!U SLB/CAMCO Equipment & Control Lines 23:30 00:00 0.50 10,689 10,703 COMPZ RPCOM RCST P Continue to Run Completion f/ 10,689' - 10703' as Follows: CAMCO TRMAXX-5E SSSV, Control Line & Clamps Mud Lost to Hole in PAst 24 Hrs = 67 Bbls Total Mud Lost this Well = 867 Bbls 6/01 /2008 Continued Running 31/2" Completion f/ 10,703' - 12,882' MD; Tagged Top of Liner Hanger @ 12,862' MD; M/U FMC Tubing Hanger, Tested Fittings to 5,000 psi f/ 5 Minutes, and P/U 9.82' Space Out Pup; Land Tubing w/ Fluted No-Go Sub Located 4' Above Liner Hanger Top; Terminated SSSV Control Line to Well Head, Installed Adapter Flange and N/U Tree; Test Both to 5,000 psi; Pulled Two-Way Check Valve; R/U to Circulate & Test Lines to 2,500 psi; Circulate Brine Below Packer as Follows: Pump 35 Bbl Hi-Vis 10.1 PPG KCL Brine, 15 Bbl 10.1 PPG KCL Brine w/Corrosion Inhibitor, 35 Bbsl of Hi-Vis 10.1 PPG KCL Brine, and 75 Bbls of 10.1 PPG KCL Brine; Drop Setting Ball & Rod; Line Up Dowell Unit to Pump & Test Lines t/ 4,500 psi; Set Packer w/ 3,500 psi; Pressure Test Tubing t/ 3,500 psi -Pressure Bled t/ 3,410 psi in 30 Minutes; Test 7 5/8" X 3 12/" Annulus t/ 3510 psi f/ 30 Minutes; Shead DCK Valve w/ 3,300 psi; Freeze Protected Well as Follows, 67 Bbls of 9.2 PPG Brine w/ Rig Pump, Switched to Dowell Pumps & Pumped 375 bbls of 9.2 PPG Corrosion Inhibited Brine, Pumped 168 Bbls Diesel w/ Dowell Unit; Shut in Well - SITP = 900 psi; FMC Installed BPV and Secured Tree; Installed Mouse Hole and La ed Down 4" DP -Pre for Ri Move 00:00 03:00 3.00 10,703 12,782 COMPZ RPCOM RCST P Continue to Run 3 1/2" tubing from 10,703' to 12,752' (403 jts. of 3 1/2" total) - XO U drill pipe -locate TOL - obseved pins shear w/ 7K SOW - t„ a~C ,_ to of Liner 12 862' -stand back DP - PUW 150K SOW 100K 03:00 05:00 2.00 12,782 12,847 COMPZ RPCOM PULD P PU/MU 3.5" x 4 .5" XO -one 4 1/2", 12.6#, L-80 space out pup (9.86') - 2 jts 4 1/2" tbg - MU wear bushing retrievin tool and ull wear bushin 05:00 06:15 1.25 12,847 12,882 COMPZ RPCOM PULD P MU FMC hanger -strip control line through hanger -pressure test fittings to 5000 psi -land hanger in wellhead with Btm. of WLEG Cad 12882', Tops of XN-nipple @ 12813', Packer @ 12,734', GLM w/SOV @ 12,676' ,GLM @ 10,771', GLM @ 5,670', SSSV 2192' 06:15 07:00 0.75 12,882 31 COMPZ RPCOM DHEQ P RILDS - LD LJ -install TWC - MU LJb -pressure test M/M hanger seals to 5000 si - LD LJb 07:00 08:30 1.50 31 31 COMPZ RPCOM NUND P PJSM - ND flowline, riser and BOP stack 08:30 11:30 3.00 31 31 COMPZ RPCOM NUND P Terminate SSSV control line to wellhead -Install adaptor flange and tree -test both to 5000 psi -Pull TWC Page ~:' 24 C~ Time Lo s Date From To Dur 5. De th E. De th Ph Code Subcode T Comment 11:30 12:00 0.50 31 31 COMPZ RPCOM RURD P RU 2" hardlines and circulating manifold 12:00 12:30 0.50 31 31 COMPZ RPCOM SFTY P Held prejob safety and Opts meeting with ri crew and su ort staff 12:30 14:00 1.50 31 31 COMPZ RPCOM CIRC P Establish circulation -test lines to 2500 psi -Pumped 35 bbls of 10.1 ppg high vis brine - 15 bbls of 10.1 ppg brine w! corrosion inhibitor - 35 bbls of 10.1 ppg High vis brine and 75 bbls of 10.1 ppg brine -FCP 3 b m 1220 si -SITP=360 si 14:00 14:45 0.75 31 31 COMPZ RPCOM PACK P RU Doyon lubricator and drop setting bal/rod - RD lubricator - RU hardline 14:45 16:30 1.75 31 31 COMPZ RPCOM DHEQ P Line up to Dowell and PT lines to 4500 psi -Set packer with 3500 psi - PT tubin ,bled to 3410 si in 30 minutes - ressure test 7 5/8" x 3 1/2" annulus to 3510 psi ,bled to 3440 si in 30 minutes Shear DCK valve with 3300 si 16:30 20:30 4.00 31 31 COMPZ RPCOM CIRC P Freeze Protected Well as Follows, 67 Bbls of 9.2 PPG Brine w/ Rig Pump -- ICP 2070 psi @ 3.5 BPM / FCP 2330 psi @ 3.0 BPM Switched to Dowell Pumps & Pumped 375 bbls of 9.2 PPG Inhibited Brine -ICP 2550 psi @ 3.8 BPM /FCP 1692 psi @ 4.0 BPM Pumped 168 Bbls Diesel w/ Dowell Unit -- ICP 1705 psi @ 3.8 BPM / FCP 1197 psi @ 2.2 BPM Shut in Well --SITP = 900 si 20:30 22:00 1.50 31 31 COMPZ RPCOM NUND P P/U Lubricator & Test U 5000 psi; Install BPV & Secure Tree w/ FMC 22:00 22:15 0.25 31 31 COMPZ RPCOM SFTY P PJSM on Installing Mouse Hole & UD Drill Pi e 22:15 00:00 1.75 31 31 COMPZ RPCOM OTHR P Install Mouse Hole & UD 4" DP for Ri Move 6/02/2008 UD 4" DP f/ Derrick, Prep Rig for Move to CD2-464 Released Ri 1200 on 2 June 2008 00:00 12:00 12.00 31 0 COMPZ RPCOM OTHR P UD 4" Dp f/ Derrick and Prep Rig for Move to CD2-464 Released Ri 1200 on 2 June 2008 F'ac~e 2~ z~f 2d WNS CD2-75 SSSV, 2,196 GAS LIFT, 5,810 GAS LIFT, 70,771 GAS LIFT, 72,678 Padcsn, 72,734 Nipple, 72,673 Loptw sub, 72,857 WLEG, 72,887 ~ 3112 i 2992 OD 12,8821 ~ 6,517.7 9.30 L-SO ~ EUE-S Rd Btm Top (TVD)Btm (TVD) r....e z^^_ Dens Shot RNR1 IRNRI IRKR\ Isho... Total 7,371.01 7,371.1 I PERF JT TD, 23,539 LastWO: 36.35 6/212008 to Annotation End Date Rev Reason: NEW WELL, Pull RHC/Plug 6!16/2008 ~~ ' '~ r r - L?ax ;. :. ~. ID pn) ID (fn)s » ToP IRKeI Set Depth (RKB) Set DepM (TVD) (RKB) Wt (ItudR) Grade Top Connettic 16 15.250 36.0 714.0 114.0 65.00 H-40 Welded ID pn) ID Pn) Top (RKB) Set DepM (RKB) Set Depth (TVD) (71K8) Wt Obs/R) Orade Top ConneMic 10 3l4 9.950 36.0 3,353.6 2,390.2 45.50 L-80 BTCM ID (in) ID (ln) Top (RKB) Set Depth (RKB) Set Depth (ND) (71KB) Wt Obs/R) Grade Top Connectk 7 5/8 6.875 -0.4 15.702.0 7,369.9 29.70 L-80 BTCM (LINER-PERF PUPS 141/21 3.958 115.198.6 I 23.539.0 I 7.355.4 I 12.60 I L-80 I IBT I Comment Set DepM i VeIVe Latch Port TRO Run Stn Top (M(B) (TVD) (RKB) Make Model OD lin) Type Type Size (in) (psi) Run Date Comment 1 5,670.4 6,517.7 CAMCO KBMG 5.39 DMY BK-5 0 0.0 6/1/2008 2 10,771.5 6,517.7 CAMCO KBMG 5.39 DMY BK-5 0 0.0 6/1/2008 3 12,675.7 6,517.7 CAMCO KBMG 5.176 OV BEK 1/4 0.0 6/3/2008 • • ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2-75 50-103-20573-00 -~ ~~ ~. + 'R ..r. ~ .w ~ .f j .1 ~ V ~`~ ~. ?~ .. i3 '3' kIl',~ ~i ~ 1 ~~ y '~ . ~{~t'~t7 Definitive Surrey Report 18 June, 2008 DEFINITIVE ~~- ~ ,, `;~i ~~~. 'Sp!er~'y ~triliir~g 3rervi ~~~~ a~~ • ConocoPhillips or its a~filiat~ ®efinitive Survey Repart Company:` ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2-75 Project: Western North Slope TVD Reference: CD2-75 @ 52.30ft (Doyon 19 (15.6 + 36.7)) Site: CD2 Alpine Pad MD Reference: CD2-75 @ 52.30ft (Doyon 19 (15.6 + 36.7)) Well: CD2-75 North Reference: True Wellbore: CD2-75 Survey Calculation Method:. Minimum Curvature Design: CD2-75 Database: EDM Alaska Prod v16 Project. Western North Slope, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factox ___ Well CD2-75 _ __ -_ Well Position +N/-S 0.00 ft Northing: 5,974,151.14 ft La titude: 70° :20' 15.316 N +E/-W 0.00 ft Easting: 371,190.51ft Lo ngitaade: 151° 2' 42.607 VV Position Uncertainty 0.00 ft Wellhead El evation: ft Ground Level: 15.60ft ~Wellbore CD2-75 - _ -- - - Magnetics Model Name .Sample Date Declination Dip Angle Fietd Strength (o ) ( ~) lnT) i BGGM2oo7 4/28/2008 17.01 79 .59 5T„228 BGGM2007 5/7/2008 17.00 79 .59 57°..,229 Design CD2-75 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.70 Vertical Section: Depth From (TVb) +NlS + E/-W Direction (ft) (ft) (ft) ~°) 36.70 _ 0.40 t i.Ur? 279.4~~ ~urvey Program Date t /18/: r ~): ~ ____ _ _ ~ From To (ft}, (ft) Survey (4Jellbore) Toul Name Description :eurvey Date 164.87 23,53 y.00 CD2-75 MWD+SAG+CA+I IFR+MS (C02 MWD+IFR-AK-CAZ-SC MWD+IFR AK CF~Z StC 5~l7/2008 12: Survey i Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Secteon (ft) O (~) (ft) (ft) (ft) ' (ft) (ft) (ft) (°/1'00') (ft~ .Survey Tool h9ame 36.70 vA0 0.00 36.7v -15.60 0.00 U.vu 5,y7~},151.i4 371,190.51 Q.00 0.00 UNDci=VNED 164.87 0.42 169.88 164.87 112.57 -0.46 0.08 5,974,150.68 371,190.59 0..33 -U.16 MWD+IFR-AK-CBaZ-SC (1) 210.01 0.49 155.49 210.01 157.71 -0.8~ 0.19 5,974,150.34 371,190.69 0.30 -0.32 MWD+IFR-AK-C64Z-SC (1) 262.73 0.86 153.62 262.72 210.42 -1.36 0.46 5,974,149.77 371,190.95 0.70 -;0.68 MWD+IFR-AK-G#AZ-SC (1) 302.38 1.33 181.95 302.37 250.07 -2.09 0.58 5,974,149.04 371,191.05 '9..77 -0.91 MWD+IFR-AK-C~1Z-SC (1) 394.37 3.26 221.55 394.28 341.98 -5.11 -1.19 5,974,146.05 371,189.23 'x.60 0.33 MWD+IFR-AK-C~AZ-SC (1) 484.92 2.94 238.14 484.70 432.40 -8.26 -4.87 5,974,142.96 371,185.50 9.05 3.44 MWD+IFR-AK-C~Z-SC (1) 577.61 6.19 243.51 577.09 524.79 -11.75 -11.37 5,974,139.59 371,178.94 3.53 9.27 MWD+IFR-AK-C~Z-SC (1) 668.75 9.61 240.58 667.35 615.05 -17.68 -22.39 5,974,133.85 371,167.82 3.78 19.17 MWD+IFR-AK-C~1Z-SC (1) 760.31 11.25 238.47 757.39 705.09 -26.10 -36.67 5,974,125.67 371,153.41 9.84 31.86 MWD+IFR-AK-CIAZ-SC (1) 851.85 14.37 234.96 846.64 794.34 -37.3® -53.58 5,974,114.77 371,136.30 3.51 46.69 MWD+IFR-AK-C~Z-SC (1) 947.26 19.52 231.78 937.88 885.58 -53.97 -75.81 5,974,098.48 371,113.79 5.48 65.87 MWD+IFR-AK-CAZ-SC (1) 992.94 21.68 230.68 980.64 928.34 -64.04 -88.34 5,974,088.63 371,101.09 4,.80 76.56 MWD+IFR-AK-C~Z-SC (1) 6/18/2008 1:15:40PM Page 2 COMPASS 2003.. '/6 Build 42F • ConocoPhi~lips or its affiliat~ Definitive Survey Report Company:. ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference` Well CD2-75 Project: We stern North Slope T~fD Refer ence: CD2-75 @ 52.30ft (Doyon 79 (15.6 + 36.7)) Site: CD2 Alpine Pad MD Reference:.. CD2-75 @ 52.30ft (Doyon 99 (15.6 + 36.7)) WeIL• CD2-75 Nc,rth Reference: True Wellbore: CD2-75 Survey Ca lculation t601ethod: Minimum C urvature Design: CD2-75 Database: EDM Alaska Prod v96 rSurvey ---- -__ --- - ___ Map Map Vertica6 MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Eastin~ DLS Section (ft) (') (~) (ft) (ft). (ft) ~~) ~ (ft) (ft) (°1100') (ft) Survey Tool Name 1,042.11 Z3.ity 230.62 1,025.97 973.67 -76.11 -103.06 5,974,076.81 371,08,.16 4.49 89.10 MWD+IFR-AK-CAZ-aG ~1) 1,136.63 25.91 229.53 1,111.70 1,059.40 -101.66 -133.57 5,974,051.79 371,055.23 2.19 114.97 MWD+IFR-AK-CAZ-SC (1) 1,231.25 26.60 228.98 1,196.56 1,144.26 -128.98 -165.28 5,974,025.02 371,023.05 0.77 141.74 MWD+IFR-AK-CAZ-SC (1) 1,326.19 28.59 233.13 1,280.70 1,228.40 -156.57 -199.50 5,973,998.03 370,98Fg.37 2.91 170.94 MWD+IFR-AK-CPcZ-SC (1) 1,421.12 33.64 237.00 1,361.96 1,309.66 -184.54 -239.75 5,973,970.76 370,947.65 5.72 206.02 MWD+IFR-AK-CAZ-SC (1) 1,467.44 35.73 237.10 1,400.04 1,347.74 -198.87 -261.87 5,973,956.81 370,925.29 4.51 225.47 MWD+IFR-AK-CP+Z-SC (1) 1,516.13 38.71 237.31 1,438.81 1,386.51 -214.82 -286.62 5,973,941.29 370,90®.26 6.13 247.26 MWD+IFR-AK-CAZ-SC (1) 1,566.86 40.07 235.95 1,478.02 1,425.72 -232.53 -313.50 5,973,924.04 370,873.09 3.17 270.85 MWD+IFR-AK-CAZ-SC (1) 1,611.27 41.28 235.09 1,511.70 1,459.40 -248.92 -337.36 5,973,908.07 370,848.95 3.00 291.68 MWD+IFR-AK-CAZ-SC (1) 1,706.76 43.19 234.30 1,582.40 1,530.10 -286.02 -389.73 5,973,871.88 370,796.95 2.08 337.21 MWD+IFR-AK-CAZ-SC (1) 1,800.98 47.60 233.15 1,648.54 1,596.24 -325.72 -443.78 5,973,833.12 370,741.23 4.76 383.98 MWD+IFR-AK-CAZ-SC (1) 1,896.83 52.32 232.99 1,710.19 1,657.89 -369.80 -502.42 5,973,790.Q5 370,681.85 4.93 434.54 MWD+IFR-AK-CAZ-SC (1) 1,992.06 55.48 234.40 1,766.29 1,713.99 -415.34 -564.43 5,973,745.59 370,619.07 3.53 488.19 MWD+IFR-AK-CAZ-SC (1) 2,087.14 57.91 234.18 1,818.50 1,766.20 -461.72 -3628.95 5,973,700.33 370,553.77 2.56 544.17 MWD+IFR-AK-CAZ-SC (1) 2,182.23 58.92 235.41 1,868.30 1,816.00 -508.41 -4695.14 5,973,654.79 370,488.80 1.53 601.75 MWD+IFR-AK-CAZ-SC (1) 2,277.29 59.04 237.70 1,917.29 1,864.99 -553.30 -763.11 5,973,611.07 370,418.07 2.07 661.39 MWD+IFR-AK-CAZ-SC (1) 2,373.60 59.17 240.48 1,966.75 1,914.45 -595.75 -X34.00 5,973,569.85 370,348.46 2.48 724.31 MWD+IFR-AK-CAZ-SC (1) 2,468.54 61.69 242.67 2,013.61 1,961.31 -635.03 -906.62 5,973,531.83 370,273.19 3.33 789.45 MWD+IFR-AK-CAZ-SC (1) 2,563.79 64.10 247.11 2,057.02 2,004.72 -670.96 -X983.38 5,973,497.22 370,195.83 4.86 859.23 MWD+IFR-AK-CAZ-SC (1) 2,658.77 65.48 247.85 2,097.47 2,045.17 -703.87 -1;1)62.76 5,973,465.683 370,115.91 1.61 932.09 MWD+IFR-AK-CAZ-SC (1) 2,753.78 66.20 248.64 2,136.36 2,084.06 -736.00 -1,143.27 5,973,434.94 370,0341.86 1.07 1,006.2.0 MWD+IFR-AK-CAZ-SC (1) 2,846.53 64.68 246.76 2,174.91 2,122.61 -768.00 -1„221.32 5,973,404.29 369,956;.28 2.47 1,077.90 MWD+IFR-AK-CAZ-SC (1) 2,943.61 63.94 245.70 2,217.00 2,164.70 -803.26 -1,:301.38 5,973,370.42 369,875.63 1.24 1,151.05 MWD+IFR-AK-CAZ-SC (1) 3,040.08 64.65 245.10 2,258.84 2,206.54 -839.44 -1,380.41 5,973,335.60) 369,798.00 0.93 1,223.03 MWD+IFR-AK-CAZ-SC (1) 3,134.92 64.39 244.47 2,299.64 2,247.34 -875.92 -1,•457.87 5,973,300.46 369,717!.93 0.66 1,293.41 MWD+IFR-AK-CAZ-SC (1) 3,229.99 67.36 243.20 2,338.50 2,286.20 -914.18 -1,335.73 5,973,263.54 369,639.43 3.35 1,363.89 MWD+IFR-AK-CAZ-SC (1) 3,315.85 64.24 246.30 2,373.69 2,321.39 -947.60 -1,806.53 5,973,231.35 369,5673.07 4.90 1,428.21 MWD+IFR-AK-CAZ-SC (1) 3,373.62 63.98 247.33 2,398.92 2,346.62 -968.06 -1,854.30 5,973,211.7'F 369,519).96 1.67 1,471.915 MWD+IFR-AK-CAZ-SC (1) 3,469.55 64.35 246.61 2,440.72 2,388.42 -1,001.84 -1,733.76 5,973,179.3'N 369,439).94 0.78 1,544.73 MWD+IFR-AK-CAZ-SC (1) 3,564.24 64.60 247.12 2,481.53 2,429.23 -1,035.41 -1,812.34 5,973,147.09 369,360).80 0.55 1,616.72 MWD+IFR-AK-CAZ-SC (1) 3,658.83 65.08 247.17 2,521.74 2,469.44 -1,068.67 -1,891.23 5,973,115.20E 369,2811.36 0.51 1,689.04 MWD+IFR-AK-CAZ-SC (1) 3,753.94 65.00 246.36 2,561.88 2,509.58 -1,102.68 -1,970.46 5,973,082.55 369,201.56 0.78 1,761.58 MWD+IFR-AK-CAZ-SC (1) 3,848.82 65.08 245.98 2,601.92 2,549.62 -1,137.44 -2,49.15 5,973,049.16 369,122.29 0.37 1,833.4.5 MWD+IFR-AK-CAZ-SC (1) 3,945.63 64.86 244.32 2,642.88 2,590.58 -1,174.30 -2,'128.74 5,973,013.67 369,042.09 1.57 1,905.88 MWD+IFR-AK-CAZ-SC (1) 4,040.24 65.35 244.05 2,682.70 2,630.40 -1,211.67 -2,:206.00 5,972,977.64: 368,9641.21 0.58 1,975.91 MWD+IFR-AK-CAZ-SC (1) 4,134.97 65.43 243.83 2,722.15 2,669.85 -1,249.50 -2,283.36 5,972,941.14' 368,8861.21 0.23 2,045.96 MWD+IFR-AK-CAZ-SC (1) 4,230.02 65.57 243.37 2,761.57 2,709.27 -1,287.96 -2,:360.84 5,972,904.02: 368,8081.09 0.46 2,116.04 MWD+IFR-AK-CAZ-SC (1) 4,324.72 65.29 243.84 2,800.95 2,748.65 -1,326.25 -2,'337.98 5,972,867.07 368,730).31 0.54 2,185.82 MWD+IFR-AK-CAZ-SC (1) 4,419.73 65.40 242.58 2,840.58 2,788.28 -1,365.17 -2,615.06 5,972,829.48` 368,652.58 1.21 2,255.42 MWD+IFR-AK-CAZ-SC (1) 4,514.36 64.32 242.19 2,880.78 2,828.48 -1,404.87 -2,690.97 5,972,791.09 368,576'1.01 1.20 2,323.7x1 MWD+IFR-AK-CAZ-SC (1) 6/18/2008 1:15:40PM Page 3 COMPASS 2003.16 Build 42F • ConocoPhiilips or its affiliat~ Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project:° Western North Slope Site: CD2 Alpine Pad Well: CD2-75 We[Ibore: CD2-75 Design: CD2-75 Survey MD Inc (ft) (°) 4,610.44 62.96 4,705.50 61.84 4,800.60 61.55 4,895.45 61.93 4,990.98 62.34 5,085.35 61.91 5,181.32 62.55 5,276.77 63.57 5,371.96 64.62 5,467.03 65.62 5,562.43 66.37 5,657.48 66.79 5,753.02 66.23 5,848.08 64.94 5,942.63 64.04 6,038.71 63.78 6,133.73 64.05 6,228.65 64.61 6,323.76 64.73 6,418.87 65.22 6,514.28 64.52 6,609.64 63.58 6,704.87 63.14 6,799.70 63.36 6,894.89 63.51 6,990.18 64.04 7,085.43 64.81 7,180.82 65.17 7,275.80 65.56 7,371.03 64.55 7,466.71 63.73 7,561.75 63.85 7,656.88 64.75 7,751.82 64.87 7,847.20 64.82 7,942.87 64.88 8,038.22 64.40 8,133.59 63.94 8,229.24 63.87 8,323.43 64.39 Azi TVD (°) (ft) 241.62 2,923.44 241.91 2,967.48 242.62 3,012.58 243.30 3,057.49 244.74 3,102.14 246.08 3,146.26 247.90 3,190.98 248.65 3,234.22 250.39 3,275.81 250.71 3,315.81 250.38 3,354.62 249.29 3,392.40 246.84 3,430.49 244.35 3,469.78 243.63 3,510.50 242.84 3,552.76 242.75 3,594.54 243.88 3,635.66 244.05 3,676.35 243.30 3,716.58 242.60 3,757.10 241.96 3,798.83 241.77 3,841.53 242.66 3,884.21 244.91 3,926.78 245.78 3,968.89 246.39 4,010.01 246.58 4,050.34 246.16 4,089.93 245.57 4,130.09 244.84 4,171.83 244.80 4,213.80 244.65 4,255.06 243.58 4,295.47 243.32 4,336.01 243.04 4,376.67 243.76 4,417.51 244.80 4,459.06 246.48 4,501.14 247.54 4,542.23 TVDSS (ft) 2, 871.14 2,915.18 2,960.28 3,005.19 3,049.84 3,093.96 3,138.68 3,181.92 3,223.51 3,263.51 3,302.32 3,340.10 3,378.19 3,417.48 3,458.20 3,500.46 3,542.24 3,583.36 3,624.05 3,664.28 3,704.80 3,746.53 3,789.23 3,831.91 3,874.48 3,916.59 3,957.71 3,998.04 4,037.63 4,077.79 4,119.53 4,161.50 4,202.76 4,243.17 4,283.71 4,324.37 4, 365.21 4,406.76 4,448.84 4,489.93 Local Co-ordinate Re°erence: Well CD2-75 TVD Reference: CD2-75 @ 52.30ft (Doyon 19 (15.6 + 36.7)) MD Reference: CD2-75; @ 52.30ft (Doyon 19 (15.6 + 36.7)) North Re ference`. True Survey C alculation Method: Minimum C urvature Database: EDM Alaska Prod v16 Map Map Vertical +Ni-S +E/-NV Northing, Fasting DLS Section ` (ft) (ft) (ft) (ft) (°/1010') (ft) Syrvey`Tool Name -1,445.41 -2,666.91 5,972,751.86 368,499.38 L.51 2,351.95 Iv1WD+fFR-AK-Ga4Z-a~, 11) -1,485.27 -2,741.13 5,972,713.29 368,424.50 1.21 2,458.58 MWD+IFR-AK-G~qZ-SC (1) -1,524.23 -2,815.24 5,972,675.61 368,349.74 0.72 2,525.25 MWD+IFR-AK-C~Z-SC (1) -1,562.21 -2,889.65 5,972,638.92 368,274.69 0.75 2,592.37 MWD+IFR-AK-CA'~Z-SC (1) -1,599.21 -2,965.57 5,972,603.24 368,198.16 1.40 2,661.15 MWD+IFR-AK-G4Z-SC (1) -1,633.92 -3,041.42 5,972,569.83 368,121.72 Y_34 2,730.23 MWD+IFR-AK-C~IZ-SC (1) -1,667.11 -3,119.57 5.,972,538.00 368,043.02 Y_81 2,801.85 MWD+IFR-AK-CA4Z-SC (1) -1,698.60 -3,198.62 5,972,507.87 367,963.45 1:28 2,874.62 MWD+IFR-AK-C~Z-SC (1) -1,728.55 -3,278.83 5,972,479.30 367,882.74 t_98 2,948.79 MWD+IFR-AK-CaAZ-SC (1) -1,757.27 -3,360.15 5,972,451.99 367,800.94 Y..10 3,024.26 MWD+IFR-AK-C.~Z-SC (1) -1,786.30 -3,442.33 5,972,424.38 367,718.29 Q85 3,100.52 MWD+IFR-AK-CJAZ-SC (1) -1,816.36 -3,524.20 5,972,395.72 367,635.92 1.14 3,176.31 MWD+IFR-AK-GI4Z-SC (1) -1,849.09 -3,605.47 5,972,364.40 367,554.11 2.42 3,251.07 MWD+IFR-AK-CAIZ-SC (1) -1,884.84 -3,684.29 5,972,330.01 367,474.69 2.74 3,322.91 MWD+IFR-AK-G~IZ-SC (1) -1,922.26 -3,760.98 5,972,293.92 367,397.38 Y_17 3,392.38 MWD+IFR-AK-G~1Z-SC (1) -1,961.12 -3,838.02 5,972,256.39 367,319.68 0.79 3,461.96 MWD+IFR-AK-CAAZ-SC (1) -2,000.13 -3,913.92 5,972,218.69 367,243.13 0:.30 3,530.38 MWD+IFR-AK-C~Z-SC (1) -2,038.55 -3,990.36 5,972,181.60 367,166.05 Y_22 3,599.43 MWD+IFR-AK-C/~Z-SC (1) -2,076.28 -4,067.60 5,972,145.20 367,088.17 0-20 3,669.40 MWD+IFR-AK=Cr~Z-SC (1) -2,114.50 -4,144.85 5,972,108.32 367,010.29 0:88 3,739.28 MWD+IFR-AK:CIAZ-SC (1) -2,153.7i~ -4,221.78 5,972,070.37 366,932.71 0.99 3,808.67 MWD+IFR-AK-C~Z-SC (1) -2,193.66 -4,297.68 5,972,031.80 366,856.13 1-16 3,876.96 MWD+IFR-AK-C~Z-SC (1) -2,233.80 -4,372.74 5,971,992.96 366,780.40 0_~0 3,944.37 MWD+IFR-AK-C.§~Z-SC (1) -2,273.2T -4,447.66 5,971,954.78 366,704.82 0.87 4,011.75 MWD+IFR-AK-C~.Z-SC (1) -2,310.88 -4,524.04 5,971,918.49 366,627.82 2_'12 4,08®.88 MWD+IFR-AK-C~Z-SC (1) -2,346.54 -4,601.72 5,971,884.18 366,549.53 0:99 4,151.62 MWD+IFR-AK-C69+Z-SC (1) -2,381.36 -4,680.26 5,971,850.71 366,470.41 0.99 4,223.34 MWD+IFR-AK-C~Z-SC (1) -2,415.86 -4,759.53 5,971,817.59 366,390.57 0.42 4,295.83 MWD+IFR-AK-C~iZ-SC (1) -2,450.46 -4,$38.63 5,971,784.35 366,310.90 0.¢17 4,3681.13 MWD+IFR-AK-C~Z-SC (1) -2,485.76 -4,917.42 5,971,750.41 366,231.51 1.20 4,440.03 MWD+IFR-AK-C.'AGZ-SC (1) -2,521.87 -4,995.59 5,971,715.65 366,152.75 1.10 4,511.16 MWD+IFR-AK-C~Z-SC (1) -2,558.15 -5,072.75 5,971,680.71 366,074.98 0.'93 4,581.29 MWD+IFR-AK-G,~.Z-SC (1) -2,594.75 -5,150.26 5,971,645.45 365,996.86 0.96 4,651.70 MWD+IFR-AK-CP~Z-SC (1) -2,632.25 -5,227.55 5,971,609.28 365;918.94 1.9'13 4,721.75 MWD+IFR-AK-CRI;Z-SC (1) -2,670.84 -5,304.78 5,971,572.02 365,841.07 0.25 4,791.55 MWD+IFR-AK-C~Z-SC (1) -2,709.92 -5,382.07 5,971,534.29 365,763.13 0.27 4,861.33 MWD+IFR-AK-C~Z-SC (1) -2,748.50 -5,459.11 5,971,497.04 365,685.44 0.65 4,930.95 MWD+IFR-AK-CR%~Z-SC (1) -2,785.75 -5,536.44 5,971,461.12 365,607.48 1.09 5,001.08 MWD+IFR-AK-C.~4Z-SC (1) -2,821.18 -5,614.69 5,971,427.05 365,528.65 1.58 5,072.42 MWD+IFR-AK-C,RLZ-SC (1) -2,854.28 -5,692.71 5,971,395.29 365,450.08 1.15 5,143.91 MWD+IFR-AK-Cr~:Z-SC (1) 6/18/2008 1:15:40PM Page 4 COMPASS 2003.` Build 42P • ConocoPhiii~ps or its aff~liat~ Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate' Reference: WeII CD2-75 Project: We stern Nort h Slope TVC~ Refer ence: CD2-75 @ 52.30ft (Dc~yon 19 (15.6 + 36.7)) Site: CD 2 Alpine P ad ' MD feference: CD2-75 @ 52.30ft (Dc~yon 19 (15.6 + 36.7)) Well: CD2-75 North Reference: True Wellbore: CD2-75 Sunaey Calculation Method: Minimum C urvature Design: CD2-75 Database: EDM Alaska Prod v15 Survey I~~ 'Map Map Vertical MD Inc Azi TVD TVDSS +Ni-S +E/-VV Northing Fasting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft)' (ft) (ft) (°/100') (ft) Survcy Tool Name 8,418.78 63.78 246.40 4,5us.y1 4,531.61 -2,887.83 -5,7T1.63 5,971,363.11 365,370.5a 1.25 5,2'16.22 MWD+I{=1t-Ak-CAZ-SC (1) 8,514.38 64.12 246.07 4,625.89 4,573.59 -2,922.44 -5,850.24 5,971,329.86 365,29L41 0.47 5,288.04 MWD+IFR-AK-CAZ-SC (1) 8,610.13 64.53 245.75 4,667.38 4,615.08 -2,957.66 -5,99.02 5,971,295.99 365,212.05 0.52 5,359.93 MWD+IFR-AK-CAZ-SC (1) 8,704.56 64.68 245.95 4,707.87 4,655.57 -2,992.56 -6,01)6.86 5,971,262.44 365,133.62 0.25 5,430.94 MWD+IFR-AK-CAZ-SC (1) 8,799.87 64.95 244.30 4,748.43 4,696.13 -3,028.84 -6,0135.10 5,971,227.51 365,054.78 1.59 5,502.13 MWD+IFR-AK-CAZ-SC (1) 8,894.88 64.28 244.26 4,789.16 4,736.86 -3,066.09 -6,162.43 5,971,191.60 364,976-82 0.71 5,572.26 MWD+IFR-AK-CAZ.-SC (1) 8,990.37 63.84 244.31 4,830.93 4,778.63 -3,103.35 -6,239.80 5,971,155.67 364,898.:83 0.46 5,642.42 MWD+IFR-AK-CAZ-SC (1) 9,085.28 64.39 244.45 4,872.37 4,820.07 -3,140.27 -6,336.79 5,971,120.08, 364,821.22 0.59 5,712.27 MWD+IFR-AK-CAZ-SC (1) 9,180.10 64.46 245.12 4,913.30 4,861.00 -3,176.71 -6,34.17 5,971,084.98 364,743.x4 0.64 5,782.57 MWD+IFR-AK-CAZ-SC (1) 9,275.22 64.28 245.11 4,954.45 4,902.15 -3,212.80 -6,471.97 5,971,050.24 364,664.84 0.13 5,853.35 MWD+IFR-AK-CAZ-SC (1) 9,370.22 64.28 244.96 4,995.67 4,943.37 -3,248.92 -6,549.56 5,971,015.46 364,586.64 0.14 5,923.92 MWD+IFR-AK-CAZ-SC (1) 9,465.35 64.12 245.30 5,037.08 4,984.78 -3,284.94 -6,fi~7.27 5,97Q,980.78 364,508.34 0.36 5,994.62 MWD+IFR-AK-CAZ~C (1) 9,559.86 64.04 245.79 5,078.39 5,026.09 -3,320.13 -6,71)4.64 5,970,946.93 364,430.37 0.47 6,065.13 MWD+IFR-AK-CAZ-SC (1) 9,655.56 64.41 246.30 5,120.00 5,067.70 -3,355.12 -6,73.40 5,970,913.30 364,35L04 0.62 6,137.04 MWD+IFR-AK-CAZ-SC (1) 9,749.16 64.01 246.79 5,160.73 5,108.43 -3,388.66 ~,815D.71 5,970,881.09 364,273..1$ 0.64 6,207.76 MWD+IFR-AK-CAZ-SC (1) 9,845.14 63.93 246.45 5,202.85 5,150.55 -3,422.89 -6,939.87 5,970,848.24 364,193.413 0.33 6,280.19 MWD+iFR-AK-CAZ-SC (1) 9,940.22 64.62 245.13 5,244.12 5,191.82 -3,458.02 -7,0'57.99 5,970,814.46 364,114.73 1.45 6,351.45 MWD+IFR-AK-CAZ-SC (1) 10,034.97 64.81 244.77 5,284.59 5,232.29 -3,494.29 -7,05.61 5,970,779.52 364,036.51 0.40 6,422.01 MWD+IFR-AK-CAZ-SC (1) 10,130.82 64.62 244.30 5,325.53 5,273.23 -3,531.55 -7,173.85 5,970,743.61 363,957.64 0.49 6,493.04 MWD+IFR-AK-CAZ-SC (1) 10,224.70 64.28 244.39 5,366.02 5,313.72 -3,568.22 -7,250.20 5,970,70$.26 363,880.68 0.37 6,562.30 MWD+IFR-AK-CAZ-SC (1) 10,319.78 63.86 244.89 5,407.59 5,355.29 -3,604.85 -7,3'w 7.47 5,970,672.97 363,802.80 0.65 6,632.46 MWD+IFR-AK-CAZ-SC (1) 10,414.84 64.41 244.98 5,449.06 5,396.76 -3,641.08 -7,4194.95 5,970,638.08 363,724.71 0.58 6,702.91 MWD+IFR-AK-CAZ-SC (1) 10,510.62 64.22 245.16 5,490.58 5,438.28 -3,677.47 -7,453.22 5,970,603.05 363,645.13 0.26 6,774.11 MWD+IFR-AK-CAZ-SC (1) 10,605.89 63.76 245.37 5,532.36 5,480.06 -3,713.29 -7,5+0.99 5,970,568.56 363,567.417 0.52 6,844.90 MWD+IFR-AK-CAZ~SC (1) 10,701.28 64.53 244.66 5,573.95 5,521.65 -3,749.55 -7,638.80 5,970,533.65 363,489.016 1.05 6,915.66 MWD+IFR-AK-CAZ-SC (1) 10,796.30 64.68 244.66 5,614.70 5,562.40 -3,786.29 -7,76.37 5,970,498.25 363,410.87 0.16 6,986.11 MWD+IFR-AK-CAZ-SC (1) 10,891.44 63.99 244.63 5,655.91 5,603.61 -3,823.01 -7,79)3.87 5,970,462.87 363,332.76 0.73 7,056.49 MWD+IFR-AK-CAZ-SC (1) 10,987.03 64.07 244.13 5,697.77 5,645.47 -3,860.17 -7,871.36 5,970,427.05 363,254.65 0.48 7,126.78 MWD+IFR-AK-CAZ-SC (1) 11,082.01 64.47 243.91 5,739.00 5,686.70 -3,897.65 -7,9138.27 5,970,390.90 363,177.111 0.47 7,196.46 MWD+IFR-AK-CAZ-SC (1) 11,177.16 64.68 244.42 5,779.85 5,727.55 -3,935.10 -8,D2~5.62 5,970,354.79 363,099.114 0.53 7,266.57 MWD+IFR-AK-CAZ-SC (1) 11,272.69 64.80 244.27 5,820.62 5,768.32 -3,972.51 -8,113.50 5,970,318.73 363,020.1x4 0.19 7,337.21 MWD+IFR-AK-CAZ-SC (1) 11,367.60 64.82 244.78 5,861.02 5,808.72 -4,009.45 -8,151.03 5,970,283.13 362,942.419 0.49 7,407.59 MWD+IFR-AK-CAZ-SC (1) 11,461.24 64.12 245.08 5,901.37 5,849.07 -4,045.25 -8,257.56 5,970,248.65 362,865.35 0.80 7,477.17 MWD+IFR-AK-CAZ-SC (1) 11,553.49 63.86 244.99 5,941.83 5,889.53 -4,080.24 -8,332.72 5,970,214.96 362,789.61 0.30 7,545.53 MWD+IFR-AK-CAZ-SC (1) 11,647.21 63.92 245.27 5,983.07 5,930.77 -4,115.63 -8,4139.08 5,970,180.88 362,712.67 0.28 7,615.00 MWD+BFR-AK-CAZ-SC (1) 11,740.78 64.15 245.16 6,024.04 5,971.74 -4,150.90 -8,455.45 5,970,146.94 362,635.70 0.27 7,684.51 MWD+IFR-AK-CAZ-SC (1) 11,834.06 64.19 245.55 6,064.68 6,012.38 -4,185.99 -8,561.76 5,970,113.24 362,558.ffi1 0.38 7,754.00 MWD+{FR-AK-CAZ-SC (1) 11,925.79 64.33 246.23 6,104.52 6,052.22 -4,219.66 -8,6337.18 5,970,080.79 362,482.82 0.68 7,822.82 MWD+IFR-AK-CAZ-SC (1) 12,017.97 64.49 246.09 6,144.33 6,092.03 -4,253.27 -8,713.23 5,970,048.51 362,406.22 0.22 7,892.28 MWD+iFR-AK-CAZ-SC (1) 12,111.06 64.61 245.94 6,184.34 6,132.04 -4,287.44 -8,7FJ0.03 5,970,015.66 362,328.£+35 0.19 7,962.39 MWD+IFR-AK-CAZ-SC (1) 6/18/2008 1:15:40PM Page 5 CC7MPASS 2003.16 Buiid 42F . ConocoPhillips or its affiiiat~ Defir3itive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD2 Alpine Pad Well: CD2-75 Wellbore: CD2-75 design: CD2-75 Survey Local Co-ordinate Reference:... Well CD2-75 TVD Reference: CD2-75 @ 52.30ft (Doyon 19 (15.6 + 36.7j) MD' Reference: CD2-75 @ 52.30ft (Doyon 19 (15.6 + 36.7)) North Reference: True Survey Ca-culation Method:. Minimum Curvature Database: EDM Alaska Prod v'!6 Map MD Ino Azi TVD TVDSS +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 12,204.18 64.33 246.58 6,224.47 6,172.17 -4,321.26 -8,866.94 5,9ti9,98s.1ti 12,297.29 63.79 246.12 6,265.20 6,212.90 -4,354.85 -8,943.64 5,969,950.90 12,390.33 63.98 245.89 6,306.15 6,253.85 -4,388.82 -9,019.96 5,969,918.25 12,483.11 64.07 244.96 6,346.79 6,294.49 -4,423.51 -9,095.81 5,969,884.87 12,574.77 64.28 246.07 6,386.72 6,334.42 -4,457.71 -9,170.90 5,969,551.97 12,663.65 64.40 246.81 6,425.21 6,372.91 -4,489.73 -9,244.33 5,969,521.22 12,757.46 64.88 247.77 6,465.39 6,413.09 -4,522.45 -9,322.53 5,969,789.85 12,850.54 65.37 250.12 6,504.55 6,452.25 -4,552.78 -9,401.33 5,969,760.88 12,943.46 65.68 252.78 6,543.05 6,490.75 -4,579.68 -9,481.50 5,969,735.36 13,037.16 65.83 255.47 6,581.53 6,529.23 -4,603.05 -9,563.67 5,969,713.41 13,131.05 65.84 256.97 6,619.97 6,567.67 -4,623.45 -9,646.86 5,969,694.44 13,223.24 66.10 258.99 6,657.51 6,605.21 -4,640.99 -9,729.21 5,969,678.33 13,315.96 67.11 261.59 6,694.33 6,642.03 -4,655.33 -9,813.08 5,969,665.43 13,409.22 67.19 264.31 6,730.55 6,678.25 -4,665.88 -9,898.36 5,969,656.35 13,502.69 67.37 266.53 6,766.66 6,714.36 -4,672.76 -9,984.29 5,969,650.94 13,594.19 67.66 268.23 6,801.65 6,749.35 -4,676.62 -10,068.75 5,969,648.53 13,687.36 68.45 269.96 6,836.48 6,784.18 -4,677.98 -10,155.15 5,969,648.65 13,779.03 68.63 271.90 6,870.02 6,817.72 -4,676.60 -10,240.45 5,969,651.50 13,871.56 69.52 274.33 6,903.07 6,850.77 -4,671.90 -10,326.74 5,969,657.69 13,963.93 70.15 276.52 6,934.91 6,882.61 -4,663.70 -10,413.05 5,969,667.37 14,054.72 70.36 278.57 6,965.59 6,913.29 -4,652.47 -10,497.76 5,969,680.04 14,148.13 70.70 280.69 6,996.72 6,944.42 -4,637.74 -10,584-58 5,969,696.26 14,241.44 71.07 282.54 7,027.28 6,974.98 -4,619.99 -10,670.93 5,969,715.49 14,332.49 71.87 283.54 7,056.22 7,003.92 -4,600.51 -10,755.03 5,969,736.41 14,425.54 72.70 285.74 7,084.54 7,032.24 -4,578.11 -10,840.79 5,969,760.28 14,519.11 72.82 286.85 7,112.27 7,059.97 -4,553.03 -10,926.56 5,969,786.83 14,611.76 73.69 288.42 7,138.96 7,086.66 -4,526.15 -11,011.11 5,969,815.15 14,705.70 74.25 290.59 7,164.91 7,112.61 -4,496.01 -11,096.21 5,969,8146.75 14,799.47 74.94 292.24 7,189.82 7,137.52 -4,463.00 -11,180.36 5,969,881.20 14,893.02 75.77 293.72 7,213.47 7,161.17 -4,427.66 -11,263-69 5,969,917.96 14,985.70 76.16 295.28 7,235.95 7,183.65 -4,390.37 -11,345.50 5,969,956.64 15,079.40 76.79 296.48 7,257.86 7,205.56 -4,350.61 -11,427.46 5,969,997.81 15,173.47 77.82 297.30 7,278.53 7,226.23 -4,309.10 --11,509.31 5,970,040.71 15,268.03 78.89 299.09 7,297.62 7,245.32 -4,265.35 -11,590-93 5,970,085.86 15,361.21 79.57 301.55 7,315.04 7,262.74 -4,219.14 -"11,669.94 5,970,133.41 15,455.35 80.44 303.17 7,331.38 7,279.08 -4,169.52 -11,748:24 5,970,184.37 15,548.76 80.45 305.13 7,346.88 7,294.58 -4,117.81 -71,824-47 5,970,237.37 15,640.11 81.20 306.18 7,361.45 7,309.15 -4,065.24 -11,897.75 5,970,291.19 15,684.93 82.64 307.47 7,367.75 7,315.45 -4,038.65 -11,933.26 5,970,318.39 15,769.33 83.85 307.66 7,377.68 7,325.38 -3,987.55 -11,999.70 5,970,370.61 Map- Vertica9 ~ Fasting DLS Section (ft) (°/100') (ft) Survey Tool Name a 362,251.37 0.69 8,032.1,18 MWD+IFR-AK-CAZ:-SC (1) 362,174.12 0.73 8,102.78 MWD+IFR-AK-CAZ'-SC (1) 362,097.23 0.30 8,172.45 MWD+IFR-AK-CAZ'-SC (1) 362,020.80 0.91 8,241.54 MWD+IFR-AK-CAZ-SC (1) 361,945.14 1.11 8,309.96 MWD+IFR-AK-CAZ'-SC (1) 361,871.17 0.76 8,377.91 MWD+IFR-AK-CAZ:_SC (1) 361,792.43 1.06 8,448.84 MWD+IFR-AK-CAZ-SC (1) 361,713.13 2.35 8,521.55 MWD+IFR-AK-CAZ~C (1) 361,632.52 2.63 8,596.99 MWD+IFR-AK-CAZ:-SC (1) 361,549.97 2.62 8,673.37 MWD+IFR-AK-CAZ-SC (1) 361,466.44 1.46 8,752.Q6 MWD+IFR-AK-CAZ-SC (1) 361,383.81 2.02 8,830.39 MWD+IFR-AK-CAZ=SC (1) 361,299.72 2.79 8,910.74 MWD+IFR-AK-CAZ'-SC (1) 361,214.27 2.69 8,993.12 MWD+IFR-AK-CAZ-SC (1) 361,128.24 2.20 9,076.74 MWD+IFR-AK-CAZ-SC (1) 361,043.74 1.75 9,159.0 MWD+IFR-AK-CAZ:-SC (1) 360,957.33 1.92 9,244.39 MWD+IFR-AK-CAZ-SC (1) 360,872.08 1.98 9,328.73 MWD+IFR-AK-CA2-5C (1) 360,785.89 2.63 9,414.64 MWD+IFR-AK-CAZ-SC (1) 360,699.74 2.33 9,50L12 MWD+IFR-AK-CAZ'-SC (1) 360,615.24 2.14 9,586.51 MWD+IFR-AK-CAZ-SC (1) 360,528.69 2.17 9,674.58 MWD+IFR-AK-CAZ-SC (1) 360,442.66 1.91 9,762.618 MWD+IFR-AK-CAZ-SC (1) 360,358.92 1.36 9,848.84 MWD+IFR-AK-CAZ-SC (1) 360,273.57 2.42 9,937.11 MWD+IFR-AK-CAZ-SC (1) 360,188.25 1.14 40,025.85 MWD+IFR~K-CAZ-SC (1) 360,104.18 1.87 90,113.617 MWD+IFR-AK-CAZ-SC (1) 360,019.62 2.30 10,202.55 MWD+IFR-AK-CAZ-SC (1) 359,936.05 1.85 90,291.0.€2 MWD+IFR-AK-CAZ-SC (1) 359,853.35 1.77 90,379.013 MWD+IFR-AK-CAZ-SC (1) 359,772.20 1.69 90,465.8 MWD+IFR-~,K-CAZ-SC (1) 359,690.93 1.42 10,553.2"8 MWD+IFR-AK-CAZ-SC (1) 359,609.82 1.39 10,640.83 MWD+IFR-AK-CAZ-SC (1) 359,528.97 2.17 10,728.57 MWD+IFR-AK-CAZ-SC (1) 359,450.77 2.69 10,814.1'2 MWD+IFR-AK-CAZ-SG (1) 359,373.34 1.93 10,899.54 MWD+IFR-AK-CAZ-SC (1) 359,298.01 2.07 '&0,983.2:5 MWD+IFR-AK-CAZ-SC (1) 359,225.66 1.40 111,064.19 MWD+IFR-AK-CAZ-SC (1) 359,190.61 4.29 11,103.61 MWD+IFR-AK-CAZ-SC (1) 359,125.06 1.45 11,177.56 MWD+IFR-AK-CAZ-SC (1) 6/18/2008 7: 95:40PM Page 6 iCOMPASS 2003.16 B~rld 42F • Conocoi'hill~ps or its affilia~ Defdnitive Survey Report Company: ConocoPhillips(Alaska) Ina .Local Co-ordinate Reference: lNell CD2-75 Project:' Western Nort h Siope TVD Reference: GD2-75 @ 52.30ft (Doyon 19 (15.6 + 36.7)) Site: CD2 Alpine P ad MD Refere nce: CD2-75 @ 52.30ft (Do yon 19 (15.6 + 36.7)) Wetl: CD2 -75 North Reference: True Wellbore: CD2-75 Survey Ca lculation Method: I'vtinimum C urvature Design: CD2 -75 Dataibasec EDM Alaska Prod v16 Survey Map A~llap Vertical MD Inc Azi TVD TVDSS +N/-S +ELUy Northing Fasting DL5 Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Narne 15,865.36 84:04 308.59 7,387.81 7,335.51 -3,928.59 -12,074.82 5,970,430.85 359,050.97 0.98 1'6,261.38 tv1WD+IFR-JaK-CAZ-SC (1) 15,959.86 84.85 311.46 7,396.96 7,344.66 -3,868.11 -12,14afi.84 5,970,492.55 358,980.01 3.14 19,342.39 MWD+IFR,AK-CAZ-SC (1) 16,055.25 86.83 313.85 7,403.88 7,351.58 -3,803.65 -12,29fi.79 5,970,558.20 358,911.'88 3.25 1'6,422.02 MWD+IFR-AK-CAZ-SC (1) 16,147.88 85.92 313.87 7,409.73 7,357.43 -3,739.60 -12,2&3.45 5,970,823.38 358,845.64 0.98 11,498.33 MWD+IFR,AK-CAZ-SC (1) 16,245.97 86.77 316.01 7,415.99 7,363.69 -3,670.45 -12,352.74 5,970,693.70 358,777.55 2.34 11,578.07 MWD+IFR AK-CAZ-SC (1) 16,340.99 88.75 319.17 7,419.70 7,367.40 -3,600.36 -12,41f.76 5,970,764.87 358,714.75 3.92 11,fi52.78 MWD+IFR-AK-CAZ-SC (1) 16,436.32 90.85 322.52 7,420.04 7,367.74 -3,526.45 -12,476.94 5,970,839.80 358,655.85 4.15 11,724.33 MWD+IFR,AK-CAZ-SC (1) 16,531.46 92.57 325.59 7,417.20 7,364.90 -3,449.48 -12,532.75 5,970,917.72 358,601.37 3.70 11,792.07 MWD+IFR,AK-CAZ-SC (1) 16,626.93 91.44 325.77 7,413.86 7,361.56 -3,370.68 -12,5.55 5,970,997.42 358,548.94 1.20 14,858.13 MWD+IFR-AK-CAZ-SC (1) 16,722.78 92.13 328.66 7,410.87 7,358.57 -3,290.15 -12,638.42 5,971,078.83 3&8,498.47 3.10 1'1,922.57 MWD+IFR-AK-CAZ-SC (1) 16,816.85 92.75 331.35 7,406.86 7,354.56 -3,208.76 -12,685.40 5,971,961.00 3x8,452.96 2.93 1'1,982.34 MWD+IFR-AK-CAZ-SC (1) 16,911.46 90.51 330.40 7,404.17 7,351.87 -3,126.15 -12,731.43 5,971,244.38 358,408.31) 2.57 12,+741.36 MWD+IFR-AK-CAZ-SC.(1) 17,006.50 89.59 330.91 7,404.09 7,351.79 -3,043.30 -12,778.00 5,971,328.01 358,363.15 1.11 12,100.96 MWD+IFR-AK-CAZ-SC (1) 17,101.59 89.79 331.72 7,404.60 7,352.30 -2,959.89 -12,823.64 5,971,412.19 358,318.96 0.88 12,159.74 MWD+IFR-AK-CAZ-SC (1) 17,195.60 89.54 332.95 7,405.15 7,352.85 -2,876.63 -12,867.29 5,971,496.18 358,276.75 1.34 12,216.52 MWD+IFR-AK-CAZ-SC• (1) 17,291.75 89.10 334.77 7,406.29 7,353.99 -2,790.32 -12,907.65 5,971,583.20 3 a8,235.~ 1.95 12,272.53 MWD+IFR-AK-CAZ-SG (1) 17,386.64 91.15 335.33 7,406.09 7,353.79 -2,704.29 -12,949.67 5,97t,6i69.89 358,197.35 2.24 12,326.20 MWD+IFR-AK-CAZ-SC (1) 17,481.59 91.39 336.67 7,403.98 7,351.68 -2,617.57 -12,98'$.28 5,971,757.25 358,160.24 1.43 12,378.58 MWD+IFR-AK-CAZ-SG (1) 17,576.52 91.95 334.68 7,401.22 7,348.92 -2,531.11 -13,023.36 5,971,844.37 358,122.65 2.18 12„431.40 MWD+IFR-AK-CAZ-SC (1) 17,669.77 90.95 332.62 7,398.86 7,346.56 -2,447.58 -13,06:E3.74 5,971,928.59 358,082.72 2.45 12,485.98 MWD+IFR-AK-CAZ-SC (1) 17,766.81 89.16 330.69 7,398.76 7,346.46 -2,362.19 -13,114.81 5,972,014.76 3x8,038.13 2.71 12.545.50 MWD+IFR-AK-CAZ-SC (1) 17,861.60 90.72 330.64 7,398.86 7,346.56 -2,279.55 -13,16'1.24 5,972,098.17 357,993.12 1.65 12,604.94 MWD+IFR-AK-CAZ-SC(1) 17,957.64 89.97 332.02 7,398.28 7,345.98 -2,195.29 -13,204.32 5,972,983.20 3x7,948.51 1.64 12,864.28 MWD+IFR-AK-CAZ-SC (1) 18,053.08 89.72 332.33 7,398.54 7,346.24 -2,110.89 -13,251.87 5,972,268.35 3517,905.42 0.42 12,722.14 MWD+IFR-AK-CAZ-SC (1) 18,148.37 90.84 331.62 7,398.08 7,345.78 -2,026.77 -13,296.64 5,972,353.21 357,862.10 1.39 12,780.17 MWD+IFR-AK-CAZ-SC (1) 18,244.26 90.21 331.49 7,397.20 7,344.90 -1,942.47 -13,34''.31 5,972,438.29 357,817.8) 0.67 12,839.13 MWD+IFR-AK-CAZ-SC (1) 18,340.02 90.22 333.01 7,396.84 7,344.54 -1,857.72 -13,386.90 5,972,523.78 3x7,774.77 1.59 12,897.08 MWD+IFR-AK-CAZ-SC (1) 18,435.82 90.65 338.51 7,396.11 7,343.81 -1,770.40 -13,426.21 5,972,611.75 357,736.96 5.76 12„950.26 MWD+IFR-AK-CAZ-SC (1) 18,483.45 91.71 341.32 7,395.13 7,342.83 -1,725.69 -13,442.56 5,972,6;56.74 357,721.38 6.30 12,973.76 MWD+IFR-AK-CAZ-SC (1) 18,531.35 91.64 340.66 7,393.73 7,341.43 -1,680.42 -13,4513.16 5,972,792.27 357,706.57 1.39 12,796.61 MWD+IFR-AK-CAZ-SC (1) 18,625.44 91.63 339.14 7,391.05 7,338.75 -1,592.10 -13,491.48 5,972,771.12 357,675.77 1.61 13,043.06 MWD+IFR-AK-CAZ-SC (1) 18,721.86 92.26 335.65 7,387.77 7,335.47 -1,503.15 -13,527.51 5,972,0.69 357,640.27 3.68 13,®94.26 MWD+IFR-AK-CAZ-SC (1) 18,817.96 89.83 332.14 7,386.02 7,333.72 -1,416.89 -13,569.78 5,972,957.65 357,599.47 4.44 13,150.18 'MWD+IFR-AK-CAZ-SC (1) 18,913.79 90.03 330.96 7,386.14 7,333.84 -1,332.63 -13,615.43 5,973,052.67 357,555.30 1.25 13,209.10 MWD+IFR-AK-CAZ-SC (1) 19,009.45 90.47 331.35 7,385.72 7,333.42 -1,248.84 -13,66'9.58 5,973,137.24 357,510.60 0.61 13,268.44 MWD+IFR-AK-CAZ-SC (1) 19,104.15 91.15 330.61 7,384.38 7,332.08 -1,166.04 -13,707.52 5,973,2"10.81 357,466.10 1.06 13,327.41 MWD+IFR-AK-CAZ-SC (1) 19,201.01 90.46 330.34 7,383.02 7,330.72 -1,081.77 -13,7565.25 5,973,3m5.88 3517,419.83 0.76 13,388.38 'MWD+IFR-AK-CAZ-SC (1) 19,296.53 89.59 327.29 7,382.98 7,330.68 -1,000.06 -13,804.70 5,973,388.42 357,371.77 3.32 13,450.64 MWD+IFR-AK-CAZ-SG (1) 19,392.03 89:54 328.79 7,383.70 7,331.40 -919.04 -13,855.25 5,973,470.29 35;7,322.64 1.57 13,513.85 MWD+IFR-AK-CAZ-SC (1) 19,487.65 91.40 329.14 7,382.92 7,330.62 -837.12 -13,90;4.54 5,973,553.04 3517,274.77 1.98 13,575.99 MWD+IFR-AK-CAZ-SC (1) 6/18/2008 1:15:40PM Wage 7 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliait~ Definitive Survey Report Company: Con ocoPhillips(Alaska) I nc. Local Co-ordinate Refe rence: Well CD2-7 5 Project:. Western Nort h Slope TVD Reference: CD2-75 @ 52.SOft (Dayon 19 (15.~ + 36.7)) Site: CD2 Alpine P ad MD Reference: CD2-75 @ 52.30ft (Dayon 19 (15.F + 36.7}} Well: CD2-75 t~Eorth Reference: Tru e Wellbore: CD2-75 Survey Calculation Met hod: 'Minimum C urvature .Design: CD2-75 Database: ,. EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) eft) (ft) (ft) (°/100') lft) Survey Toai Name' '19,581.57 91.51 330.44 7,380.53 7,328.23 -755.98 -13,951.79; 5,973,634.97 357,228.93 1.39 13,635.97 N1WD+IFR-Alf-CAZ-SC(kj 19,679.67 91.39 330.09 7,378.05 7,325.75 -670.82 -14,000.43 5,973,720.94 357,181.76 0.38 13,697.99 MWD+IFR-AIK-CAZ-SC (~) 19,775.49 90.40 330.92 7,376.55 7,324.25 -587.43 -14,047.60;1 5,973,805.12 357,136.04 1.35 13,758.27 MWD+IFR-AK-CAZ-SC(E) 19,871.31 90.84 331.25 7,375.52 7,323.22 -503.56 -14,093.92- 5,973,889.77 357,091.16 0.57 13,817.79 MWD+IFR-AK-CAZ-SC(11) 19,966.66 89.96 330.92 7,374.85 7,322.55 -420.10 -14,140.02 5,973,974.00 357,046.50 0.99 13,877.03 MWD+IFR-AK-CAZ-SC(1d) 20,062.27 89.66 331.77 7,375.17 7,322.87 -336.21 -14,185.87 5,974,058.67 357,002.11 0.94 13,936.09 MWD+IFR-Alf-CAZ-SC(E) 20,158.30 90.41 334.70 7,375.11 7,322.81 -250.47 -14,229.1'1- 5,974,145.13 356,960.35 3.15 13,992.88 MWD+IFR-AK-CAZ-SC(1!) 20,254.05 90.96 334.50 7,373.96 7,321.66 -163.99 -14,270.1i~. 5,974,232.30 356,920.78 0.61 14,047.65 MWD+IFR-AIC-CAZ-SC (11) 20,349.76 90.58 333:03 7,372.68 7,320.38 -78.15 -14,312.48` 5,974,318.85 356,879.96 1.59 14,103.53 MWD+IFR-Alf-CAZ-SC(R) 20,445.02 90.59 332.99 7,371.71 7,319.41 6.73 -14,355.71 5,974,404.45 356,838.20 0.04 14,160.17 MWD+IFR-AK-CAZ-SG (11) 20,538.30 90.21 334.17 7,371.05 7,318.75 90.27 -14,397.22" 5,974,488.68 356,798.14 1.33 14,214.89 MWD+IFR-Alf-CAZ-SG ('R) 20,636.29 90.65 334.09 7,370.32 7,318.02 178.44 -14,439.97 5,974,577.56 356,756.91 0.46 14,271.60 MWD+IFR-Alf-CAZ-SC (~) 20,732.16 90.96 333.97 7,368.97 7,316.67 264.62 -14,481.95. 5,974,664.44 356,716.42 0.35 14,327.22 MWD+IFR-Alf-CAZ-SC ('q) 20,827.72 91.45 332.66 7,366.96 7,314.66 349.98 -14,524.85. 5,974,750.52 356,674.99 1.46 14,383.61 MWD+IFR-AK-CAZ-SC (R) 20,923.59 90.21 331.78 7,365.57 7,313.27 434.79 -14,569.53 5,974,836.08 356,631.78 1.59 14,441.67 MWD+IFR-Alf-CAZ-SC (11;) 21,019.22 89.78 329.16 7,365.58 7,313.28 517.99 -14,616.66; 5,974,920.07 356,586.09 2.78 14,501.88 MWD+IFR-AFr.-CAZ-SG {'R) 21,114.93 89.85 330.24 7,365.89 7,313.59 600.62 -t4,664.95> . 5,975,003.51 356,539.23 1.13 14,563.13 MWD+IFR-AK-CAZ-SC (~) 21,210.59 90.40 331.75 7,365.68 7,313.38 684.28 -14,711.33: 5,975,087.95 356,494.30 1.68 14,622.68 MWD+IFR-Alf-CAZ-SC {1i) 21,306.41 90.03 332.48 7,365.32 7,313.02 768.97 -14,756.14 5,975,173.39 356,450.95 0.85 14,680.85 MWD+IFR-AK-CAZ-SC (Y) 21,402.05 90.47 335.56 7,364.91 7,312.61 854.94 -14,798.03' 5,975,260.05 356,410.55 3.25 14,736.35 MWD+IFR-AK-CAZ-SC (1') 21,496.22 90.21 337.97 7,364.35 7,312.05 941.46 -14,835.1& 5,975,347.20 356,374.89 2.57 14,787.26 MWD+IFR-AK-CAZ-SC (1'") 21,591.94 91.08 337.01 7,363.27 7,310.97 1,029.88 -14,871.82' 5,975,436.23 356,339.78 1.35 14,837.98 MWD+IFR-Alf-CAZ-SC (1:,) 21,687.52 90.83 334.31 7,361.68 7,309.38 1,116.94 -14,911.21 5,975,523.95 356,301.90 2.84 14,891.19 MWD+IFR-AK-CAZ-SC (1) 21,783.10 89.53 334.93 7,361.38 7,309.08 1,203.30 -14,952.17" 5,975,610.98 356,262.42 1.51 14,945.84 MWD+IFR-AK>CAZ-SC (1`) 21,878.98 90.03 335.10 7,361.74 7,309.44 1,290.20 -14,992.67 5,975,698.57 356,223.43 0.55 15,®00.12 MWD+IFR-AK-CAZ-SC (1) 21,974.62 89.84 336.03 7,361.85 7,309.55 1,377.28 -15,032.23 5,975,786.30 356,185.37 0.99 15,®53.50 MWD+IFR-AK=CAZ-SC (1') 22,070.37 90.09 335.80 7,361.91 7,309.61 1,464.69 -15,071.31 5,975,874.36 356,147.81 0.35 15,906.46 MWD+IFR-AK-CAZ-SC ('F) 22,166.16 90.03 334.41 7,361.81 7,309.51 1,551.58 -15,111.63. 5,975,961.92 356,108.99 1.45 15,160.56 MWD+IFR-AK-CAZ-SC (~) 22,261.92 90.09 332.92 7,361.71 7,309.41 1,637.40 -15,154.11 5,976,048.45 356,067.99 1.56 15,216.61 MWD+IFR-AK-CAZ-SC (1 22,357.62 90.28 332.64 7,361.40 7,309.10 1,722.50 -15„197.8& 5,976,134.29 356,025.69 0.35 15,273.83 MWD+IFR-AK-CAZ-SC (1') 22,451.13 90.15 331.65 7,361.05 7,308.75 1,805.17 -15,241.57" 5,976,217.69 355,983.43 1.07 15,330.56 MWD+IFR-AK,-CAZ-SC (1; 22,549.74 90.40 331.07 7,360:58 7,308.28 1,891.71 -15,288.84 5,976,305.03 355,937.66 0.64 15,391.45 MWD+IFR-AK-CAZ-SC (1?) 22,644.85 89.78 330.92 7,360.43 7,308.13 1,974.89 -15,334.96 5,976,388.98 355,892.98 0.67 15,450.65 MWD+IFR-AK~CAZ-SC (1;) 22,740.57 89.91 331.69 7,360.69 7,308.39 2,058.86 -15,380.91 5,976,473.71 355,848.48 0.82 15,509.83 MWD+IFR-AK~AZ-SC (1 22,836.45 90.47 331.14 7,360.37 7,308.07 2,143.05 -15,426.79 5,976,558.67 355,804.06 0.82 15,568.97 MWD+IFR-AK-CAZ-SC (1j 22,930.23 90.52 329.81 7,359.56 7,307.26 2,224.65 -15,473.00 5,976,641.05 355,759.26 1.42 15,628.01 MWD+IFR-AK-CAZ-SC (1,) 23,025.30 90.65 324.69 7,358.59 7,306.29 2,304.57 -15,524.41 5,976,721.84 355,709.23 5.39 15,691.90 MWD+IFR-AK-CAZ-SC (1 23,074.89 89.40 322.38 7,358.57 7,306.27 2,344.45 -15,553.88 5,976,762.21 355,680.45 5.30 15,727.54 MWD+IFR-AK-CAZ-SC (1 j 23,120.40 89.16 322.31 7,359.14 7,306.84 2,380.48 -15,581.68. 5,976,798.71 355,653.28 0.55 15,760.90 MWD+IFR-AK CAZ-SC (1~ 23,217.66 89.17 324.69 7,360.55 7,308.25 2,458.65 -15,639.52. 5,976,877.85 355,596.79 2.45 15,}330.85 MWD+IFR-AK-CAZ-SC (1)) 6/?8/2008 1:15:40PM Pale 8 COMPASS 203.16 Build 42F . ConocoPhillip~ or its affilia~ Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Go-ordinate Reference:. Well CD2-75 Project: ' Western North Slope TVA Reference: - CD2-75 @ 52.30ft (Doyon 19 (15.6 +36.7)) Site: CD2 Alpine Pad MDR Reference: CD2-75 @ 52.30ft (G-oyon 19 (15.6 +36.7)) Well: CD2-75 North t~eference: True Wellbore: CD2-75 Survey Calculation Method: Minimum Curvature Design:. CD2-75 Database: EDtd~l Alaska Prod v16 Survey Map Map Vertical MD lnc Azi TVD TVDSS +N/-S +EhVH Northing Easting DLS Section (ft) (°) (°) (ft) (ft) ` (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 23,313.95 91.28 328.23 '7,360.18 7,307.88 2,538.89 -15,692.71 5,976,958.99 355,544.99 4.28 15,rsa6.54 MWUD+IFR-AK-CP~Z-SC (1) 23,410.38 91.20 329.00 7,358.09 7,305.79 2,621.19 -15,742.9 5,977,042.13 355,496.21 0.80 15,959.64 MWVD+IFR-AK-CAZ-SC {1) 23,539.00 91.20 329.00 7,355.40 7,303.10 2,731.41 -15,809.1 5,977,153.47 355,431.89 0.00 16,043.14 MIND+IFR-AK-CL4~Z-SC (1) &/18/2008 1:15:40PM Page 9 C®AH~'ASS 2003.1 Build 42F ~ ~ WELL L®G TRANSMITTAL To: State of Alaska June 24, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-75 AK-MW-5772459 CD2-75 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20573-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20573-00 Digital Log Images: 1 CD Rom 50-103-20573-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Q Signed: ~O~--OCo~I ~ a CQ (P ~o a • WELL LOG TRANSMITTAL To: State of Alaska June 20, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD2-75 AK-MW-577245 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: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20573-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ,I Signed: i 19-Jun-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-75 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 36.70' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 23,539.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~?~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) obi- ac,~ ConocoPhillips Alaska CD2-75~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, May 31, 2008 8:12 AMv~ ~ To: Crumrine, Tim William Cc: Alvord, Chip; Chambers, Mark A; Galiunas, Elizabeth C; Doyon 19 Company Man Subject: RE: ConocoPhillips Alaska CD2-75 Tim, et at, Sorry I wasn't able to get back with you earlier by email. We did talk about 16:30 or so. Unfortunate that the assembly got stuck. Short of milling and fishing, there aren't many options. Setting the hanger at the current depth will allow a significant portion of the well to be productive. Setting packers "high" is not unusual at Alpine, although as you note the packer is ususally set below the TOC. It is not likely that completing the well this way will lead to an early failure. As noted in the conversation, it is acceptable to continue with the operations. Tom Maunder, PE AOGCC From: Crumrine, Tim William [mailto:Tim.W.Crumrine@conocophillips.com] Sent: Fri 5/30/2008 3:20 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Chambers, Mark A; Galiunas, Elizabeth C; Doyon 19 Company Man Subject: ConocoPhillips Alaska CD2-75 Dear Mr. Maunder: As per our telephone conversation this afternoon, ConocoPhillips is currently in the process of running the 4-1/2 perforated pup liner lower completion of the CD2-75 producer. After stopping to make a connection we were unable to move the liner up or down. Numerous attempts have been made to move the liner with no luck. This puts the liner hanger at 12861' MD RKB, which is 2300' MD above the original landing point and above the estimated 7-5/8" intermediate casing top of cement at 13620'. ConocoPhillips is requesting approval to set the liner hanger at its current depth of 12861' and continue with completing the well. Please reply to all when answering this request. Yours very truly, Tim Crumrine, P.E. Completions Engineer Alaska Drilling and Wells ConocoPhillips +1-907-265-6402 Office +1-907-230-2964 Mobile 6/2/2008 • Page 1 of 1 Maunder, Thomas E (DOA) From: Doyon 19 Company Man [doyon1@conocophillips.com] Sent: Thursday, May 29, 2008 7:20 PM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C Subject: RE: CD2-75 Closed upper ram for Exhale test. Tom, The last full BOP test was completed on 5/19/08. Since Liz will be out of the office tomorrow I thought I should provide you the information requested. Cheers Dave Burley From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 29, 2008 4:07 PM To: Galiunas, Elizabeth C Cc: Alvord, Chip; Chambers, Mark A; Doyon 19 Company Man Subject: RE: CD2-75 Closed upper ram for Exhale test. Liz, et al, Thanks for the information. Testing when out of the hole is appropriate. When was the last full BOP test performed? Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Thursday, May 29, 2008 3:54 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Chambers, Mark A; Doyon 19 Company Man Subject: FYI: CD2-75 Closed upper ram for Exhale test. Tom, a o~-o c~ y While tripping out of the hole on CD2-75 after the lateral was TD'ed, the welt was breathing. We performed a breathing test/exhale test, therefore we closed the top VBRs. I attached a good explanation from our morning report with the details. We will be testing the upper VBRs once out of the hole. Let myself, the Rig, or Chip know if you need any more information. Thanks, Liz Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-441-4871 5/30/2008 • Security Level: Daily Drilling Report CD2-75 Report Number: 25 ,, ,, . Rig: DOYON 19 Report Date: 5/28/2008 AFE Type NetworkllD # _ _ Total AF_E+Sup Drilling 10218060 11,248,054.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK6) Depth End (ftK6) 0.00 22,600.0 22,600.0 i CD2-75 Development ALPINE 22.53 25_0 _ --- - - Daily Mud Cos` tr ,.~~ A~umulative M~~a ~ ;, ~ Daily Cost Tot ~ ~umul fir}' ' T' ~ `tr/~ ~ .------ _ , Actual Start Date TOrginal Spud Date E Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 28 /2008 06 ~ : 5!6/2008 36.98 40.62 -3.64 6/14 5/4/2008 --- ~-- th (ftK6) t C i S t D N D - ng e ep ex as Next Casing O (in) LastCasing String ~ 23,577.00 Intermediate, 15,702.OftK6 _ j4 1/2 Ops and Depth ~ Morning Report 24hr Forecast Change Saver Sub, C&S Drill Line @ 13,331' MD ~ Pump Out of Hote 30 Stands / C&S DriIlLine /POOH & Run 4 1!2" Liner Last 24hr Summary ~ I Continued to Circulate and Weight Up Mud System to 11.0 PPG; Back Reamed Out-of--Hole f/ 23,156' - 15,708' MD; Circulate, Condition 8~ Weight Up Mud System t/ 11.3 PPG; Conduct Well Bore Exhale Test; Bled Back 25.05 Bbls During Test; Total Mud Lsot to Hole for Past 24 Hrs = 389 Bbls General Remarks Weather Head Courrt No Accidents, No Spills 30 / WC 30 /Wind Calm 50.0 Supervisor -- Title _ Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Lo Start .End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code OpSub-Code P- t`i-T Trbl Code Trbl Class. (ftK6) (ftK6) Operation 00:00 06:15 6.25 _ PROD1 _ DRILL CIRC _ T Well Control Lost Circ - 23,156.0 22,995.0 Continue to circulate and wt. up mud to 6:15 2:00 ~ 5.75 i PF20D1 I RILL RIP P - Other ~ I 2,995.0 ~ ~ 20,000.0 11.0 ppg - 3 bpm / 1420 psi / 60 rpm - Set back one stand / 30 minutes from 23,156' to 22,295' -mud wt. in & out 11.0 pP9 bpm / 1680 psi / 60? pmto 20,000' - 4 I i Mud wt. out 11.0 - 10.6 ppg - mamtam ' mud wt. in at 11.0 ppg ~ ~ PUW 240 K SOW 140 K Rt.Wt. 175 k Rot Torque 16 K @ 20,000' i ~ i , ("Lost 109 bbls of mud in last 12 hours 12:00 17:45 5.75 1 PROD1 DRILL TRIP P 20,000.0 15,708.0 Continue to BROOH f/ 20,000' - 15,708' 1660 Psi 40 SPM MD 17:45 21:45 4.00 PROD1 i WELCTL COND 'T Well Control Lost Circ - 15,708.0 15,708.O @ ; Circ & Condition Mud; Weight Up System' _ i Other i ~f/ 11.0 - 11.3 PPG i i i I I I ~ i i - J - - -- _._ _ - -- I 'Latest BOP Test Data -- - --_ - - - _ Carnment Date -_ _ - _ __ !3500, Chuck Scheve waived witnessing of test. _ _ _ _ _______ 250/25 0 0 5/19/2008 _ _ _ __ Page 1/3 Report Printed: 5!29/2008' --- - -- - - • I - - - - -- ~-- - ~ it L l S eve : ecur y Da ily Drillin g Repo rt CD2- 75 Report Number: 25 Time L Start Time 21:45 . . o End Time 00:00 • Dur (hrs} 2.25 I Rig: Phase PROD1 DOYON 19 Op Code WELCTL ~ pSub-Code OTHR - Time P--'t-T T - Trbl Code Well Control rbl Class. Lost Circ - Other epth Start (ftK8) 15,708.0 ' epth End (ttKB) 15,708.0 ( ~ Report Date: 5/28/20081 - Operation Conduct 6chale Test as Follows: Shut Down Pumps, Monitor Flow, and R/U i Pressure Gauges to DP and Choke ll f/ 10 Mi tes it ld M d W f ' i ~ nu ore on e Mani o ; Flow Decreased f/ 18 % - 11 %, Rate Decreased f/ 90 BPH - 45 BPH; Over 10 ! j Minute Observation Well Bled Back 13.5 I Bbis ** Well Not Flowing Through I I i ( Choke** I i I Shut Well In and Observed Pressures Build and Stabilize as Follows: SIDPP Increased f/ 160 - 184 Psi; SICP i ( Increased f/ 172 - 176 Psi I ( i ~ i Bled Annulus Through Choke f/ 10 minutes as Follows: SIDPP Decreased f/ i I ' ~ ' i i 184 - 82 Psi, SICP Dropped to 0 Psi; Flow Rate Decreased f/ 48 - 24 BPH; Total Mud Bled Back = 6.3 Bbls i I i Shut Well In and Observed Pressures I I I Build and Stabilize as Follows: SIDPP I Increased f/ 96 - 105 Psi; SICP Increased I f/ 133 - 146 Psi I ~ I i Bled Annulus Trough Choke f/ 10 I Minutes as Follows: SIDPP Decreased f/ i 105 - 26 Psi; SICP Dropped to 0 Psi; BPH, f/ i ; I j 5.25 BbI Total Mud Bled Back ; Shut Well In and Observed Pressures ~ Build and Stabilize as Follows: SIDPP i I j I Increased f/ 20 - 22 Psi; SICP Increased ' f/ 84 - 100 Psi I ~ i Opened Choke and Drill Pipe & I ; Monitored Well; Flow Decreased f/ 8.4 - i ~ 3.24 BPH in 1 hr ~ i i ' ' ~ Total Mud Lost to Hole f/ 12 Hr Period = i 280 Bbls I ~ ! ! i I i ~ Total Mud Lost to Hole f/ 24 Hr Period = i 389 Bbls I I Mud T Flo-Pr I heck ype o NT ' ata Depth 23, ftK~6) Dens pbl 540.0 11 ' aq Vis (s/qt) PV .30 51 ' I YP Ca Calc (cp) (Ibf/100 18.0 26. c ft~ p 000 el (10s) Gel b1/100ft~ (Ibf 8.0, ~ (10m) Gel (3 /100tt) (ibf/10 9.0 10 ' 0m) 0f1~) MBT .000 I ~ H Qtt/btN) (m 2.0 ~ I THP FR Density Temp .Solids, Corr: l~~nin) PH_ (-F} (°~°) i 9.1 i 17.5 i ~flo-Pr o NT 23, 540.0 11 .00 491 17.0, 25. 000 7.0 8.0 9 .000 2.0 9.0 16.5 I ~ _ gilt Strings: BHA No. 5 - 5200 Geo Pilot ! Bit Run No. 4 RR1 - 6 3/4in, Halliburton Secu DBS , FMF3641Z, 10796971 I Depth In (ftKB) -Depth Out (ftK6) TFA (incl Noz) (in') Noales (132") ~ - ~IADC Bit Dull - ~ String Wt (1000ibf) ~7.0 i- 23,539.0 0.52 I 15/15/15 ~_ - - - 9 I i i Page 2/3 Report Printed: 5/29/2008 r~ Security Level: Daily Drilling Report CD2-75 Report Number: 25 . ,• Rig: DOYON 19 Report Date: 5/28/2008 Drill Strin Com onents Jts _ ~saiptron Item OD (in) ID (in) Top Coruui Sz (in) .Top Thread Cum Len (ft) 1 _ __ _ Geo Pilot _ 4 3/4 1.500 3 1/2 NC 38 17.49 1 Drill Collar -Flex Non Mag 43/4 1.500 ~ 3 1/2 NC 38 29.00 1 MWD DM HOC 4 3/4 1.500 3 1/2 NC 38 37.41, 1 Smart Stabilizer (Non Mag) 4.76 1.500 3 1/2 NC 38 41.00 1 MWD GRlRES 4.73 1.500 3 1/2 NC 38 65.53 1 MWD (Geo-Tap) w/ PWD 4 3/4 1.500 3 1/2 NC 38 89.47 1 MWD TM HOC 4.62 1.500 3 1/2 NC 38 99.49 I 1 Float Sub ~ 4.66 2.313 3 1/2 ( NC 38 101.81 ~ 1 NMDC ~ 4.68 2.250 3 1/2 NC 38 132.97 I 1 NMDC ~ 4.56 2.250 3 1/2 NC 38 164.12 1 NMDC 4.521 2.250 3 1/2 NC 38 195.26 1 XO Sub 4.8 2.563 4 XT 39 197.17 3 HWDP 4 2.563 ~ 4 XT 39 288.94 1 Drilling Jars - DNT 4 3/4 ~ 2.000; 4 XT 39 320.94 i 382.11 ~ 2 HWDP 4 2.563 4 XT 39 382.11 Drillin Parameters Flow Rate Sliding (gPm) RPM PU Str Wt Drill Str Wt SO Str Wt Start (ftK6) End (ftK6) Cum Depth (ft) Cum Dell Time (hrs) Time (hrs) (gP~n) WOB (Ibf) UD~n) SPP (psi) (to~bfl (~~d1 (~~b~ Off Btm Tq DriN Tq 22,600.0, 23,539.0 7,802.00 73.65 0.00 265 14.0 120 3,700.0 250 175 0 17,500.0- 18,500.0 Weiibores _ _ _ Wellbore Name Wellbore APIAJYVI CD2-75 501032057300 Section Act Top (ftKB) Size (in) Ad Btrn (ftK6) Start ate Erxi Date ___ COND1 _ ____ 36 36.0 114.0 2/20/2008 2/21/2008 SURFAC 131/2' 114.0 3, 363.0 5/6/2008 5/8/2008 ~ INTRM1 9 718 3,363.0 15, 717.0 5/10/2008 5/15/2008 I PROD1 _ 6 3/4 15,717.0 _ 5/22/2008 _~ i I I , i i i I i I i ~ I i I i i ~ _ -- - -_ - ~ __ - - Page 3/3 --_- Report Printed: 5/29/2008' F.._ '~~.a~' ~•.~ ~~ ~.~ ~..r ~ ~ ~1 u_. t_9~ ~~ ~ .~~~ ~ i.-~~. (~.J,1 _~ d..I w~ I A SARAH PAL/N, GOVERNOR ~~ OIL ~ ~ 3~ ANCHORAGE, ALASKA~9950103539 CO1~T5I:RQATIOPIT COMl~IIS5I0IQ f PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD2-75 ConocoPhillips Alaska, Inc. Permit No: 208-064 Surface Location: 2215' FNL, 2043' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 4707' FNL, 1996' FEL, SEC. 32, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). DATED this Z~day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL y~ 20 AAC 25.005 1 ~~ APR 1 8 2008 Alaska Oil & Gas Cons. Commission Anchorage 1a. Type of Work: Drill Q Re-drill Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zon~ Single Zone ^ 1c. Specify if well is proposed for: , Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD2-75 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 23577' TVD: 7347' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section)/ Surface: 2215' FNL, 2043' FEL, Sec 2, T11 N, R4E, UM 7. Properly Designation: ADL 380075, 387207, ASRCNPRA02 Alpine Oil Pool Top of Productive Horizon: ~ 968' FNL, 3441' FEL Sec 9, T11 N, R4E, UM 8. Land Use Permit: 380075 13. Approximate Spud Date: 5/4/2008 Total Depth: J 4707' FNL, 1996' FEL, Sec 32, T12N, R4E, UM 9. Acres in Pro e p rty: 2560 14. Distance to..3~~ ~, (,L Nearest Prope 5 A .., 9~i ~/ i~P~ .az • 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371190. y- 5974151.1 Zone- 4 A ,~,` 10. KB Elevation 52.3 L- ~7, l i (Height above GL): 37' RKB feet 4• 15. Distance to Nearest Z~''S Well within Pool: CD2-59 1793' at 19750' MD 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3324 psig Surface: 2589 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 13.5" 10-3/4" 45.5# L-80 BTCM 3327 37 37 3364 2395 672 sx ASL3, 270 sx 15.8 cl G 9.875" 7-5/8" 29.7# L-80 BTCM 15661 37 37 15698 7366 168 sx LiteCrete, 253 sx 15.8 cl G, 269 sx cl G for K2 6.75" 3.5" 9.3# L-80 EUE-M 15517 32 32 15549 7347 Tbg 6.75" 4.5" 12.6# L-80 IBTM 8369 15198 7347 23567 7346 perforated and blank Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume rylp Np Conductor/Structural Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketcl^ Drilling Prograr^ Time v. Deptl^~t Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketcl^ Seabed Repor^ Drilling Fluid Pro ~ 20 AAC 25.050 requirementsQ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Ga/lungs Printed Name C. Alvord Title WNS Drilling Team Lead Signature r / Phone 2 6 ~- _ r'o ~~ Date s~- ~ (-~ ~ 2,9 ~ ej C•~ Commission Use Only Permit to Drill ' / y Number: Z~ ~ / API Number: 2 m 50- ~~3' ~J /3 -~Zj Permit Approval /' • ' Ug Date: See cover letter for other re uirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce Coalbedfm~ethane, gas hydrates, or s twined in shales: ~-~Q S c ~~r '~ CS ~ Samples req'd: Yes ^ No u ~ g r q'd: Yes ^ No ,~ Other. ~ H2S measures: Yes ^ No [~ ~ c i re ~ Yes ~o ^ 1J sJ~~1Gai3~~ ~~~a"S.GS~C~~C~~ ~D DATE: ~ R ~ ~ ~ ~ ROVED BY THE COMMISSION i rnnnnniccintir=R 1 VIM IV-YVI --- - --- •% r ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 C Cono~oPhilli s April 18, 2008 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-75 R~~~f~ APR Y 8 C~~~ Dear Sir or Madam: ~a411;8 0118 ~ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore produ *rom t e " ' 2 drilling pad. The intended spud date for this well is 05/04/08. It is intended that Doyon Rig 19 be used to drill the well After setting 7-5/8" intermediate casing, the horizontal section will be drilled and the well completed with a perforated liner and tubing. At the end of the rig work program, the well will be flowed back for 2-3 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin production. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. After running 7-5/8" casing, it is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At CD2, there has not been a significant show of shallow gas or gas hydrates through the / surface hole interval `' 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. A proposed drilling program. 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the 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. 3. Riser setup If you have any questions or require further information, please contact Liz Galiunas, 265-6247, or Chip Alvord at 265-6120. Sincerely, ~+/+ ~~DB Liz Galiunas Drilling Engineer Attachments cc: CD2-75 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Nina Anderson ATO 1704 Tim Schnieder ATO 1706 Lanston Chin Kuukpik Corporation CDZ-75 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 1 ~_1 /7" Hnla / 1 fl_~/d" (_acinn Interval Event Risk Level Miti anon Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud ~ weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations / >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 9-7/8" Hole / 7-5/8" Casino Interval Event Risk Level Miti anon Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 peg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure / mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low J H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ~_3/d" Hnle / Hnri~nntal Production Hole Event Risk Level Miti anon Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 peg. Pressure / Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well '' control ractices, mud scaven ers ORIGINAL Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. ~~ 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD). ' 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 3500 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 9-7/8" drilling BHA. 9. Drill 9-7/8" hole to intermediate casing point in the Alpine D. (LWD Program: GR/RES/PWD) 10. Run and cement 7-5/8" casing as per program. Carry out a leak off test down the 10-3/4"x7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 3500 psi. 12. Drill 6-3/4" horizontal section to well TD (LWD Program: GR/RES/PWD). 13. Circulate the hole clean and pull out of hole. 14. Run lower completion with 4-1/2" perforated liner and liner hanger. 15. Run 3-'/2, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, packer, XN nipple and stinger assembly. Sting in, space out and land hanger. 16. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 17. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 18. Circulate tubing to diesel and install freeze protection in the annulus. 19. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 20. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-72 is the nearest existing well to the CD2-75 plan at 55' well to well separation at 347' MD. Drilling Area Risks: There are no high-risk events. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD2-75 will be injected into a permitted annulus on CD2, or the class 1 disposal well on CD1 pad. The CD2-75 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 Nanuq reservoir and there will be 500' of cement fill above the top of the Nanuq as per regulations. Upon completion of CD2-75 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. 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 near the base of the Schrader Bluff Formation (C-40). 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 = 2997 psi Pore Pressure. = 1,131 psi Therefore Differential = 2997 -1131 = 1866 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: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 10-3/4" 45.5 L-80 3 BTC-M 2480 2108 psi 3580 psi 3043 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi ORIGINAL ~.I DRILLING FLUID PROGRAM SPUD to 10-3/4"surface Intermediate hole to 7- 5/8"" i Production Hole casing point - 13- cas ng point - 9-7/8" Section - 6 3/4" Densit PV y 1/2 8.8 - 9.6 pp9 9.6 - 9.8 pp9 YP 20-60 10-25 9.8-10.5 pp9 ~ 10-15 Funnel Viscosity 100 - 200 15-25 25 - 30 Initial Gels 10 minute gels 4 - 8 10 - 15 API Filtrate HPHT Fluid Loss at 160 NC - 10 cc / 30 min `18 4 - 12 cc/30 min (drilling) 12 - 20 PH KCL 8.5_9.0 g.0-10 0 12-14 cc/30 min . 9.0-9.5 6% Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line 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 Nechelik 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 low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. Higher mud weight due to offset injectors east of CD2-75. ~R!GINAL • Completion Schematic Colville River Field CD2-75 Production Well Completion Final Updated 04/14/08 16" Conductor to 114' Sperry Drilling WP09 - 4-'/i' space out pups -3--'/" x 4 ''/i' cross-over, 2 jts below 4-'/2" hanger 3-1/2" Camco TRMAXX-5E SSSV Nipple (2.813" ID) i -2.813" X-Over t Packer Fluid mix: -Single'/<"x0.049" s/s control line Diesel in tubing and annulus " Uooer Completion MD TVD 10-3/4 45.5 ppf L-80 BTC-mod 1) Tubing Hanger 32' 32' Surface Casing 2) 4 ''/2' 12.6 #/ft IBT-Mod Tubing (2) @ 3364' MD / 2395' TVD 3) 4'/:" 12.6 #Ift IBT-Mod SPACE OUT PUPS a cemented to surface 4) Crossover Cement to +/- 66 4' c~ 5) 3-1/2", 9.3#/ft, EUE-Mod Tubing MD / 3842' TVD 6) Camco TRMAXX-5E SSSV w/ x profile 2200' 1881' 7) 3-1/2", 9.3#/ft, EUE-Mod Tubing 8) Camco KBMG GLM (2.867" ID) w/dummy 5673' 3400' Qannik interval top +/- 9) 3-1/2", 9.3#/ft, EUE-Mod Tubing 7194' MD / 4059' TVD 10) Camco KBMG GLM (2.867" ID) w/dummy 10751' 5600' ~, ~ 11) 3-1/2", 9.3#/ft, EUE-Mod Tubing a H ES Stage Tool +/- 12) Camco KBMG GLM (2.867" ID) w/DCK2 shear ' ' 13550' 6789' 7740' MD / 4295' TVD 13) 3 /~ 9.3#/ft, EUE-M (1) 14) Baker 3.5" X 7-518" Premier Packer 13600' 66807' 15) 3-Yz' 9.3#/ft, EUE-M (2) 16) HES "XN" 12.75" min IDl @ 68° 13700' 6731' 17) 3 '/i' 9.3#/ft, EUE-M io 18) 3 '/~' 9.3#/ft, EUE-M with mule shoe WLEG sub 15549' 7347' -c~ Camco KBMG GLM (2.8s7" ID) bottom, 3' above Top of liner @ 15578' E Dummy with 1" BK-2 Latch Lower Completion: Top MD TVD 19) Baker 5"x7" Flexlock Liner Hanger w/setting sleeve (500' up from shoe) 15198 7283' 21) 4-'/:" 12.6#/ft L-80 IBTM Tubing 22) Easy Well Swell Packer -For Fault near heel TBD 21) 4 'h" 12.6#!ft L-80 IBTM Tubing with 5' Perforated pups 22) Baker Shoe 23567' 7346' l\ ~s Swell Packers as TOC @ +/- 12400 MD / 6314' ND ' 14 '•-- contingency " 6 '/ l 300 above packer depth _ a O e ~s 20 zz Top Alpine D 15424 MD / 7326 Dom. \ 0 0 0 0 0 0 0 0 00 0° 00 00 0 0 00 - 21 Top Alpine B 15579 MD / 7351 TVD Top Alpine A 15833 MD / 7378 TVD " 4-''/i' 12.6#/ft L-80 IBTM liner, Well TD at 7-5/8 29.7 ppf L-80 BTC Mod 1 ea 5 ft perforated pup with 23,577' MD / Production Casing @ rigid straight centralizer per 4 7347' TVD 15,698' MD / 7366' TVD joints Landed in Alpine B ORIGINAL w ~ PRESSURE INFORMATION (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: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling in MD/TVD ft lbs. / al si si 16 114 / 114 10.9 52 53 10-3/4" 3364 / 2395 14.5 1083 1566 7-5/8" 15698 / 7366 16.0 3333 2589 N/A 23577 / 7347 16.0 3324 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE ASP ASR 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) - 0.1]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./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 Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D - [(OR9 x 0.052) - 0.1] x 114 = 53 psi ASP =FPP - (0.1 x D) = 1083 - (0.1 x 2395') = 844 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2395 = 1566 psi OR ASP =FPP - (0.1 x D) = 3333 - (0.1 x 7366) = 2596 psi Drilling below intermediate casing (7-5/8") ASP =FPP - (0.1 x D) = 3324 - (0.1 x 7347') = 2589 psi ORIGINAL Cementing Program: 10-3/4" Surface Casing run to 3339' MD 12400' TVD. Cement from 3364' MD to 2864' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2864' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1569' MD). Lead slurry: (2864-1569') X 0.3637 ft3/ft X 1.5 (50% excess) = 706.5 ft3 below permafrost 1569' X 0.3637 ft3/ft X 4 (300% excess) = 2282.6 ft3 above permafrost Total volume = 706.5 + 2282.6 = 2989.1 ft3 => 672 Sx @ 4.45 ft3/sk System: 672 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 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% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft = 43.1 ft3 shoe joint volume Total volume = 272.8 + 43.1 = 315.9 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, + 1 %S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7-5/8" Intermediate Casing run to 15698 MD 17366' TVD Second Stage: Cement from 15698' MD to 15168' MD (500' of Class G + adds @ 15.8 PPG) and from 15168' to 13300' with LiteCRETE @ 11.0 ppg (minimum 300' MD above the packer). Assume 40% excess annular volume. Lead: (15168'-13300') X 0.2146 ft3/ft X 1.4 (40% excess) = 561.2 ft3 annular vol. Total Volume = 561.2 ft3 => 168 Sk @ 3.35 ft3/sk System: 168 Sx LiteCrete with 0.4% D046 antifoamer, 1.0 % D065 dispersant, 0.010% 6155 retarder, 0.25% D167 fluid loss @ 11.0 PPG yielding 3.35 ft3/sk Tail: (15698' - 15168') X 0.2146 ft3/ft X 1.4 (40% excess) = 273.1 ft3 annular vol. 80' X 0.2577 ft3/ft = 20.6 ft3 shoe joint volume Total volume = 273.1 + 20.6 = 293.7 ft3 => 253 Sx @ 1.16 ft3/sk System: 253 Sx Class G + Class G + 1 %S2, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +l- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (7740'-6694') X 0.2146 ft3/ft X 1.4 (40% excess) = 314.3 ft3 annular vol. Total Volume = 314.3 ft3 => 269 Sk @ 1.17 ft3/sk System: 269 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement r~~~r{~IAf_ ~ ~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad Plan: CD2-75 Plan: CD2-75 Plan: CD2-75wp09 Standard Proposal Report 11 April, 2008 1-iALLIBUI~'rC'~N 13perry Drilling 8®rvicse~ ORIGINAL ~~ r system: IscwsA Scan McNOtl: Trav. Cylintler North Ertor SUrFace: Elliptical cOOIC Western North Slope COf10CO~1 VIeV~.V„ ~~~~PS Warning Methotl: Rules 6asetl ' 1" Geodetic Datum: NortltAmerlwn DaNm 19B~ Magnetlc Model: BGGM290] CD2 Alpine Pad ~'D2.75wp09 Plan: CD2-75 Ground Level: 16.00 RKB: Planned C79 !or AW ~ 52.90ft (Doyon 19 (36.9+16)1 Plan: CD2-75 Northing/ASP V: 59i 989. 81 Fasting/ASP X: 1511225.21 CD2-I 5v1~y~~9 Y 15~p~g Gp2 2500 4-1/2" x 6-3/4" CD2-75wp07 Toe C O 0 _ 4" x 13-1/2" _ 10-3/ ~ ~ O Z .-. ~ 2500 - - O 7-5/8" x 9-7l8" ~ ~I i ~~ CD2-75wp09 Heel i 5000 ' - -- - - --- -15000 -12500 -10000 -7500 -5000 -2500 0 West(-)/East(+) (2500 ft/in) 0 - 0 o, ~ o 3 ~ 10-3/4" x 13-1/2" ~ ~~'~ o N 2500 -_ ... C-30 C-20 ~ K-3 Marker Basal K-3 ~_ ~ --= ---- ~ Basal K-2 K-2 Marker ~o~ 5000 Albian sz ______ a~ ~ I i r --- Albian 96 O --- -- ~ HRZ Base HRZ K-1 Marker Kuparuk Fm LCU-Miluveach ' - - - - -, - - - - -- - - 7-5/8" x 9-7/8" 4-1/2" x 6-3/4" -- so _- o T _ - -- - -_ 7500 AI ine A-' Miluveach A ' p Alpine B~Alpine C=Alpine D- _ - - ~ m p - CD2 CD2-75w 09 Heel 0 N' p07 Toe 0 2500 5000 7500 10000 12500 15000 0 O V r~ 1 ooL/u 6700 6800 6900 7000 7100 7200 7300 7400 7500 10900 11900 12900 13900 14900 15900 16900 17900 18900 19900 20900 Along Well Departure (AWD) Comments: Con ocoPhilliq(Alarkc)Inc.~WNS C'tl COrrecROn: -0.99 lob NO: Werfern Notlh Sla pe Mpgnellc OecAnoflon: 22.13 AFE No: CD3-)Swp09 Dip: 80.68 API No: MN/A Doyley per 100 ft Syrlem (w D) Reference: Original VS %ona: 2]9.09 Parent Well: 1511339.21 tt View VS Plane: 2]9.99 RRB MeighY. 59)389).81 tf UnB Sy~lem: ie ~ CD2-75wp09 Plan kN/A IN/A MN/A Mean Sea Level Plan: CD3-]5 53.90 tt API Ba setl ~ FPS i i i I_ I I Along Well View Page 1 of 1 (Toolboxl) 4/11/2008 11:59 AM Operobn Reb: W NI: Rlq: SVrlace Locaflon x: r: Along-the-wellbore n 0 E 0 • CD2-75wp09 Report Operator: ConocoPhillips(Alaska) Inc. -WNS Grid Correction: -0.99 Job No: Field: Western North Slope Magnetic Declination: 22.13 AFE No: Well: CD2-75wp09 Dip: 80.6E API No: Rig; Dogleg per: 100 ft North Reference: 'fRlJ17 Surface Location Original VS Plane: 279.49 Parent Well: Plan: CD2-75 X: ~ 371190A6 "ft Vlew VS Plane: 303 RKB Height (above system 52.30 ft Y: 5974151.12 ft Start Date: Ol /Ol /00 TD Da}e: Ol /Ol /00 Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original ie ass wmn~o~,°a Tool Dist from Drilled ~,m ~.iottl1 11D1 Depth (ft) Angle (deg) Azi. (deg) TVD (ft) TVD (11) N(+)/S(-) (ft) E(+)/W(-) (TO N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (279°) (ft) (3 (f0 21046 (R) Face (deg) VS Plane (ft) Distance (ft) Comments ~ 7 l l).~,.~-t_l ! .~4 Luu 36.30 0.00 0.00 -16.00 36.30 0.00 0.00 5974151.12 371190.46 ~ 0.00 0.00 ## 0.00 0 0.00 100.00 0.00 0.00 47.70 100.00 0.00 0.00 5974151.12 371190.46 0.00 0.00 ## 0.00 0 0.00 63.70 CB-GYRO-SS 1 200.00 0.00 0.00 147.70 200.00 0.00 0.00 5974151.12 371190.46 0.00 0.00 ## 0.00 0 0.00 163.70 300.00 0.00 0.00 247.70 300.00 0.00 0.00 5974151.12 371190.46 0.00 0.00 ## 0.00 0 0.00 263.70 KOP; 2.3 DLS 400.00 2.30 230.00 347.67 399.97 -1.29 -1.54 5974149.86 371188.90 2.30 1.30 ## 2.01 230 -1.53 363.70 2.32 0.6 500.00 4.60 230.00 447.49 499.79 -5.16 -6.15 5974146.07 371184.23 2.30 5.21 ## 8.02 0 -6.10 463.70 4.62 1.57 ~~ 550.00 5.75 230.00 497.28 549.58 -8.06 -9.60 5974143.23 371180.72 2.30 8.14 ## 12.53 0 -9.53 513.70 5.77 1.86 600.00 7.25 231.04 546.96 599.26 -11.65 -13.97 5974139.71 371176.29 3.00 11.86 ## 18.19 5 -13.79 563.70 7.28 2.12 700.00 10.24 132.20 645.78 698.08 -21.06 -25.90 5974130.51 371164.20 3.00 22.07 ## 33.39 4 -25.05 663.70 10.27 2.54 800.00 13.24 232.85 743.68 795.98 -33.43 -42.06 5974118.42 371147.84 3.00 35.97 ## 53.73 3 -39.91 763.70 13.28 2.86 900.00 16.24 233.26 840.38 892.68 -48.71 -62.39 5974103.50 371127.25 3.00 53.50 ## 79.17 2 -58.33 863.70 16.28 3.11 000.00 19.74 233.26 935.48 987.78 -6'7.18 -87.13 5974085.46 371102.19 3.50 74.85 ## 110.04 0 -80.63 963.70 19.78 3.34 1100.00 23.24 233.26 1028.52 1080.82 -89.09 -116.47 5974064.06 371072.48 3.50 100.18 ## 146.66 0 -107.08 1063.70 MWD+IFR-AK-C 23.28 3.54 200.00 26.74 233.26 1119.14 1171.44 -114.35 -150.31 5974039.39 371038.21 3.50 129.39 ## 188.90 0 -137.58 1163.'70 26.78 3.71 1300.00 30.24 233.26 1207.02 1259.32 -142.88 -188.53 5974011.53 370999.51 3.50 162.38 ## 236.58 0 -172.02 1263.70 30.28 3.87 1400.00 33.74 233.26 1291.83 1344.13 -174.57 -230.97 5973980.58 370956.53 3.50 199.01 ## 289.54 0 -210.27 1363.70 33.78 4.01 00.00 37.24 233.26 1373.24 1425.54 -209.29 -277.48 5973946.67 370909.44 3.50 239.15 #k 347.59 0 -252.19 1463.70 37.28 4.13 00.00 40.74 233.26 1450.96 1503.26 -246.92 -327.88 5973909.92 370858.39 3.50 282.66 ## 410.49 0 -197.62 1563.70 40.78 4.25 1700.00 44.24 233.26 1524.69 1576.99 -287.32 -382.00 5973870.46 370803.60 3.50 329.37 ## 478.02 0 -346.39 1663.70 44.28 4.36 1800.00 47.74 233.26 1594.17 1646.47 -330.33 -439.62 5973828.45 370745.25 3.50 379.10 ## 549.92 0 -398.32 1763.70 47.78 4.46 1900.00 51.24 233.26 1659.12 1711.42 -375.81 -500.53 5973784.04 370683.57 3.50 431.68 ## 625.94 0 -453.22 1863.70 51.28 4.55 2000.00 54.74 233.26 1719.31 1771.61 -423.57 -564.50 5973737.40 370618.78 3.50 486.90 ## 705.77 0 -510.88 1963.70 54.78 4.64 2100.00 56.56 233.83 1775.74 1828.04 -471.44 -631.75 5973690.70 370550.72 2.80 545.33 ## 788.33 50 -569.19 2063.70 57.57 4.72 2200.00 58.44 238.29 1829.47 1881.77 -517.28 -702.53 5973646.09 370479.17 2.80 607.58 ## 872.67 49 -626.07 2163.70 60.37 4.79 2300.00 60.36 240.65 1880.37 1932.67 -560.98 -776.67 5973603.68 370404.29 2.80 673.50 ## 958.74 47 -681.41 2263.70 63.17 4.86 2400.00 62.33 242.93 1928.33 1980.63 -602.44 -854.00 5973563.57 370326.27 2.80 742.93 ## 1046.49 46 -735.05 2363.70 65.98 4.9 2500.00 64.33 245.12 1973.22 2025.52 -641.55 -934.33 5973525.84 370245.28 2.80 815.70 ## 1135.84 45 -786.89 2463.70 68.77 4.9 2600.00 64.33 245.12 2016.54 2068.84 -679.47 -1016.09 5973489.35 370162.88 0.00 890.09 ## 1225.97 0 -837.77 2563.70 68.78 5.03 2700.00 64.33 245.12 2059.87 1112.17 -717.38 -1097.86 5973452.56 370080.48 0.00 964.48 ## 1316.10 0 -888.65 2663.70 68.79 5.06 2800.00 64.33 245.12 2103.19 2155.49 -755.30 -1179.62 5973416.36 369998.08 0.00 1038.87 ## 1406.23 0 -939.54 2763.70 68.80 5.10 2900.00 64.33 245.12 2146.51 2198.81 -"793.22 -1261.39 5973379.87 369915.68 0.00 1113.26 ## 1496.36 0 -990.42 2863.70 68.81 5.13 3000.00 64.33 245.12 2189.83 2242.13 -831.13 -1343.15 5973343.37 369833.28 0.00 1187.66 ## 1586.48 0 -1041.30 2963.70 68.81 5.16 3100.00 64.33 245.12 2233.16 2285.46 -869.05 -1424.92 5973306.88 369750.58 0.00 1262.03 ## 1676.61 0 -1092.18 3063.70 68.82 5.19 3200.00 64.33 245.12 2276.48 2328.78 -906.96 -1506.68 5973270.38 369668.48 0.00 1336.44 ## 1766.74 0 -1143.07 3163.70 68.83 5.22 3300.00 64.33 245.12 2319.80 2372.10 -944.88 -1588.45 5973233.89 369586.08 0.00 1410.83 ## 1856.87 0 -1193.95 3263.70 68.84 5.25 3353.54 64.33 245.12 2343.00 2395.30 -965.18 -1632.23 5973214.35 369541.96 0.00 1450.66 ## 1905.13 0 -1221.20 3317.24 C-30 68.55 5.26 3364.39 64.33 245.12 2347.70 2400.00 -969.29 -1641.10 5973210.39 369533.02 0.00 1458.73 ## 1914.90 0 -1226.72 3328.09 10-3/4" x 13-1/2" 68.86 5.27 3400.00 64.33 245.12 2363.13 2415.43 -982.79 -1670.21 5973197.39 369503.68 0.00 1485.22 ## 1947.00 0 -1244.83 3363.70 68.56 5.28 3500.00 64.33 245.12 2406.45 2458.75 -1020.71 -1751.98 5973160.90 369421.28 0.00 1559.61 ## 2037.13 0 -1295.72 3463.70 68.87 5.30 3600.00 64.33 245.12 2449.77 2502.07 -1058.62 -1833.74 5973124.40 369338.88 0.00 1634.00 ## 2127.25 0 -1346.60 3563.70 68.88 5.32 3700.00 64.33 245.12 2493.10 2545.40 -1096.54 -1915.51 5973087.91 369256.48 0.00 1708.39 ## 2217.38 0 -1397.48 3663.70 68.89 5.35 3800.00 64.33 245.12 2536.42 2588.72 -1134.45 -1997.27 5973051.42 369174.08 0.00 1782.78 ## 2307.51 0 -1448.37 3763.70 68.90 5.37 (CD2-75wp09.xls) Page 1 of 6 4/17/2008 3:29 PM CD2-75wp09 Report Meas. Incl. TRUE Subsea I1KB Lo cal ASP o r Grid Dogleg Original ie nn«wmeo,<n<wmo-< Tool Dist from Drilled lurro„am. UDI 21046 77 `` I f)? 7 V Q4 7 Depth Angle Azi. TVD TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity VS (279°) (3 Face VS Plaae Distance Comments ~ . • I ~!~~ (ft) (deg) (deg) (ft) (ft) (ft) (ff) Lat. (Y) Dep. (X) (°/100 ft) (ft) (fq (ft) _ (deg) (ft) (ft) ~ 00 3900 64 33 245.12 2579.74 2632.04 -1172.37 -2079.04 5973014.92 369091.68 0.00 1857.17 ## 2397.64 0 -1499.25 3863.70 68.90 5.39 . . 64 33 12 245 2623 06 2675.36 -1210.28 -2160.50 5972978.43 369009.28 0.00 1931.57 ## 2487.77 0 -1550.13 3963.70 68.91 5.41 4000.00 0 . 64 33 . 12 245 . 2666 39 2718 69 -1248.20 -2242.57 5972941.93 368926.88 0.00 2005.96 ## 2577.90 0 -1601.02 4063.70 68.92 5.43 4100.0 00 4200 . 64 33 . 12 245 . 2709 71 . 2762.01 -1286.11 -2324.33 5972905.44 368844.48 0.00 2080.35 ## 2668.02 0 -1651.90 4163.70 68.93 5.45 . . 64 33 . 12 245 . 2727 00 2779 30 -1301 25 -2356.97 5972890.87 368811.59 0.00 2110.04 ## 2703.99 0 -1672.21 4203.61 C-20 68.94 5.45 4239.91 00 00 . 64 33 . 245 12 . 03 2753 . 2805.33 . -1324.03 -2406.10 5972868.94 368762.08 0.00 2154.74 ## 2758.15 0 -1702.78 4263.70 68.94 5.46 . 43 4400 00 . 64 33 . 245.12 . 2796.36 2848.66 -1361.94 -2487.87 5972832.45 368679.68 0.00 2229.13 ## 2848.28 0 -1753.67 4363.70 68.95 5.48 . 00 00 . 64 33 245 12 68 2839 2891.98 -1399.86 -2569.63 5972795.95 368597.28 0.00 2303.52 ## 2938.41 0 -1804.55 4463.70 68.96 5.50 . 45 4600 00 . 64 33 . 245 12 . 2883 00 2935.30 -1437.77 -2651.40 5972759.46 368514.88 0.00 2377.91 ## 3028.54 0 -1855.43 4563.70 68.97 5.51 . . 4 33 . 245 12 . 2926 32 2978 62 69 -1475 -2733.16 5972722.96 368432.48 0.00 2452.30 ## 3118.67 0 -1906.32 4663.70 68.98 5.53 4700.00 0 . 6 64 33 . 245 12 . 65 2969 . 95 3021 . -1513 60 -2814.93 5972686.47 368350.08 0.00 2526.69 ## 3208.80 0 -1957.20 4763.70 68.99 5.55 4800.0 4900 00 . 64 33 . 245 12 . 30]2 97 . 3065.27 . -1551.52 -2896.69 5972649.97 368267.68 0.00 2601.08 ## 3298.92 0 -2008.08 4863.70 68.99 5.56 . 000 00 . 33 64 . 245 12 . 29 3056 3108.59 -1589.44 -2978.46 5972613.48 368185.28 0.00 2675.47 ## 3389.05 0 -2058.97 4963.70 69.00 5.58 . 5 00 00 . 64 33 . 245 12 . 3099 62 3151 92 -1627.35 -3060.22 5972576.98 368102.88 0.00 2749.57 ## 3479.18 0 -2109.83 5063.70 69.01 5.59 . 51 0 00 . 64 33 . 12 245 . 3142 94 . 3195 24 -1665.27 -3141.99 5972540.49 368020.48 0.00 2824.26 ## 3569.31 0 -2160.73 5163.70 69.02 5.60 - . 520 00 5300 . 64 33 . 245.12 . 3186.26 . 3238.56 -1703.18 -3223.75 5972504.00 367938.08 0.00 2898.65 ## 3659.44 0 -2211.62 5263.70 69.03 5.62 . 00 5400 . 64 33 245.12 3229.59 3281.89 -1741.10 -3305.32 5972467.50 367855.68 0.00 2973.04 ## 3749.57 0 -2262.50 5363.70 69.03 5.63 . 00.00 . 64.33 245.12 3272.91 3325.21 -1779.01 -3387.28 5972431.01 367773.28 0.00 3047.43 ## 3839.69 0 -2313.38 5463.70 69.04 5.64 65 5 600 00 64 33 245.12 3316.23 3368.53 -1816.93 -3469.05 5972394.51 367690.88 0.00 3121.82 ## 3929.82 0 -2364.27 5563.70 69.05 . . 00.00 . 64.33 245.12 3359.55 3411.85 -1854.84 -3550.81 5972358.02 367608.45 0.00 3196.21 ## 4019.95 0 -2415.15 5663.70 69.06 5.67 68 5 00 00 64 33 245.12 3402.88 3455.18 -1892.76 -3632.58 5972321.52 367526.08 0.00 3270.60 ## 4110.08 0 -2466.03 5763.70 69.07 . . 00 00 . 64 33 245.12 3446.20 3498.50 -1930.67 -3714.34 5972285.03 367443.68 0.00 3344.99 ## 4200.21 0 -2516.92 5863.70 69.07 5.69 . 00 000 . 64 33 245.12 3489.52 3541.82 -1968.59 -3796.11 5972248.53 367361.28 0.00 3419.38 ## 4290.34 0 -2567.80 5963.70 69.08 5.70 . 00 00 . 64 33 245.12 3532.85 3585.15 -2006.50 -3877.87 5972212.04 367278.88 0.00 3493.78 ## 4380.46 0 -2618.68 6063.70 69.09 5.71 . 200 00 . 64 33 245.12 3576.17 3628.47 -2044.42 -3959.64 5972175.54 367196.48 0.00 3368.17 ## 4470.59 0 -2669.57 6163.70 69.10 5.72 . 300 00 . 64 33 245.12 3619.49 3671.79 -2082.33 -4041.41 5972139.05 367114.08 0.00 3642.56 ## 4560.72 0 -2720.45 6263.70 69.11 5.73 . 00.00 . 64.33 245.12 3662.81 3715.11 -2120.25 -4123.17 5972102.56 367031.68 0.00 3716.95 ## 4650.85 0 -2771.33 6363.70 69.11 5.74 5 75 00 00 64 33 245.12 3706.14 3758.44 -2158.16 -4204.94 5972066.06 366949.28 0.00 3791.34 ## 4740.98 0 -2822.22 6463.70 69.12 . . 6600 00 . 64 33 245.12 3749.46 3801.76 -2196.08 -4286.70 5972029.57 366866.88 0.00 3865.73 ## 4831.11 0 -2873:10 6563.70 69.13 5.76 . 6 75 11 . 64 33 245 12 00 3782 3834 30 -2224.56 -4348.11 5972002.15 366804.99 0.00 3921.61 ## 4898.80 0 -2911.32 6638.81 K-3 Marker 69.14 5.77 . 6 00 . 64 33 . 12 245 . 3792 78 . 3845 08 -2233.99 -4368.47 5971993.07 366784.48 0.00 3940.12 ## 4921.23 0 -2923.98 6663.70 69.15 5.77 6700. 6800 00 . 64 33 . 245.12 . 3836.11 . 3888.41 -2271.91 -4450.23 5971956.58 366702.08 0.00 4014.51 ## 5011.36 0 -2974.87 6763.70 69.16 5.78 . 6900 00 . 64 33 245.12 3879.43 3931.73 -2309.82 -4532.00 5971920.08 366619.68 0.00 4088.90 ## 5101.49 0 -3025.75 6863.70 69.16 5.79 . 7000 00 . 64 33 245.12 3922.75 3975.05 -2347.74 -4613.76 5971883.59 366537.28 0.00 4163.29 ## 5191.62 0 -3076.63 6963.70 69.17 5.80 . 7100 00 . 33 64 245.12 3966.07 4018.37 -2385.66 -4695.53 5971847.09 366454.88 0.00 4237.69 ## 5281.75 0 -3127.52 7063.70 69.18 5.81 . 7127 53 . 64 33 245.12 3978.00 4030.30 -2396.09 -4718.03 5971837.05 366432.19 0.00 4258.16 ## 5306.56 0 -3141.52 7091.23 Basal K-3 69.19 5.8 . 7194 47 . 64 33 245.12 4007.00 4059.30 -2421.47 -4772.77 5971812.62 366377.04 0.00 4307.96 ## 5366.89 0 -3175.58 7158.17 K-2 Marker 69.20 5.82 . 7200 00 . 64 33 245.12 4009.40 4061.70 -2423.57 -4777.29 5971810.60 366372.47 0.00 4312.08 ## 5371.58 0 -3178.40 7163.70 69.20 5.82 . 7300 00 . 64 33 245.12 4052.72 4105.02 -2461.49 -4859.06 5971774.10 366290.08 0.00 4386.47 ## 5462.00 0 -3229.28 7263.70 69.21 5.83 . 8 36 . 64 33 245 12 4091 00 4143 30 -2494.99 -4931.30 5971741.86 366217.27 0.00 4452.20 ## 5541.64 0 -3274.24 7352.06 Basal K-2 69.22 5.84 . 738 7400 00 . 64 33 . 245.12 . 4096.04 . 4148.34 -2499.40 -4940.82 5971737.61 366207.67 0.00 4460.86 ## 5552.13 0 -3280.17 7363.70 69.23 5.84 . 7500 00 . 64 33 245.12 4139.37 4191.67 -2537.32 -5022.59 5971701.11 366125.27 0.00 4535.25 ## 5642.26 0 -3331.05 7463.70 69.24 5.$4 . 7600 00 . 33 64 245.12 4182.69 4234.99 -2575.23 -5104.35 5971664.62 366042.87 0.00 4609.64 ## 5732.39 0 -3381.93 7563.70 69.24 5.85 . 00 00 . 64 33 245 12 4226 01 4278 31 -2613.15 -5186.12 5971628.12 365960.47 0.00 4684.03 ## 5822.52 0 -3432.81 7663.70 69.25 5.86 . 77 00 7800 . 64 33 . 245.12 . 4269.34 . 4321.64 -2651.06 -5267.88 5971591.63 365878.07 0.00 4758.42 ## 5912.65 0 -3483.70 7763.70 69.26 5.87 . 7900 00 . 33 64 245.12 4312.66 4364.96 -2688.98 -5349.65 5971555.14 365795.67 0.00 4832.81 ## 6002.77 0 -3534.58 7863.70 69.27 5.88 . 8000 00 . 64 33 245.12 4355.98 4408.28 -2726.89 -5431.41 5971518.64 365713.27 0.00 4907.20 ## 6092.90 0 -3585.46 7963.70 69.28 5.$S . 8100 00 . 64 33 245.12 4399.30 4451.60 -2764.81 -5513.18 5971482.15 365630.87 0.00 4981.60 ## 6183.03 0 -3636.35 8063.70 69.28 5.89 . 8200 00 . 33 64 245.12 4442.63 4494.93 -2802.72 -5594.95 5971445.65 365548.47 0.00 5055.99 ## 6273.16 0 -3687.23 8163.70 69.29 5.90 . 8300 00 . 64 33 245 12 4485 95 4538.25 -2840.64 -5676.71 5971409.16 365466.07 0.00 5130.38 ## 6363.29 - 0 -3738.11 8263.70 69.30 5.91 . . . . 27 4529 4581 57 -2878 55 48 -5758 5971372.66 365383.67 0.00 5204.77 ## 6453.42 0 -3789.00 8363.70 69.31 5.91 8400.00 64.33 245.12 . . . . (CD2-75wp09.xls) Page 2 of 6 4/17!2008 3:29 PM CD2-75wp09 Report Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original ie nu~r weuc aa ~w~ TOOI Dist from Drilled -I~.n r..~~t:~, UhI g 2146 7~) ~ ~)~ 7 ~4 th De Angle Azi. TVD TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity VS(279°) (3 Face VSPlaae Distance Comments . . p (ft) (deg) (deg) (ft) (t4) (ft) (ft) Lat. (Y) Dep. (X) (°/100 ft) (ft) (fq (ft) (deg) (ft) (ft) ~ r.Uo 00 8500 64 33 245.12 4572.60 4624.90 -2916.47 -5840.24 5971336.17 365301.27 0.00 5279.16 ## 6543.55 0 -3839.88 8463.70 69.32 5.92 . 00 8600 . 64 33 245.12 4615.92 4668.22 -2954.38 -5922.01 5971299.67 365218.87 0.00 5353.55 ## 6633.67 0 -3890.76 8563.70 69.33 5.93 . 00 5700 . 64 33 245.12 4659.24 4711.54 -2992.30 -6003.77 5971263.18 365136.47 0.00 5427.94 ## 6723.80 0 -3941.65 8663.70 69.33 5.93 . 0 . 33 64 245 12 56 4702 86 4754 -3030 21 -6085.54 5971226.68 365054.07 0.00 5502.33 ## 6813.93 0 -3992.53 8763.70 69.34 5.94 8800.0 00 8900 . 64 33 . 245.12 . 4745.89 . 4798.19 . -3068.13 -6167.30 5971190.19 364971.67 0.00 5576.72 ## 6904.06 0 -4043.41 8863.70 69.35 5.95 . 9000 00 . 64 33 245.12 4789.21 4841.51 -3106.04 -6249.07 5977153.69 364889.27 0.00 5651.11 ## 6994.19 0 -4094.30 8963.70 69.36 5.96 . 00 9100 . 64 33 245.12 4832.53 4884.83 -3143.96 -6330.83 5971117.20 364806.87 0.00 5725.51 ## 7084.32 0 -4145.18 9063.70 69.37 5.96 . 9200 00 . 64 33 245.12 4875.86 4928.16 -3181.88 -6412.60 5971080.71 364724.47 0.00 5799.90 ## 7174.44 0 -4196.06 9163.70 69.37 5.97 . 9300 00 . 64 33 245.12 4919.18 4971.48 -3219.79 -6494.36 5971044.21 364642.07 0.00 5874.29 ## 7264.57 0 -4246.95 9263.70 69.38 5.97 . 9400 00 . 64 33 245.12 4962.50 5014.80 -3257.71 -6576.13 5971007.72 364559.67 0.00 5948.68 ## 7354.70 0 -4297.83 9363.70 69.39 5.98 . 00 9500 . 64 33 245.12 5005.83 5058.13 -3295.62 -6657.89 5970971.22 364477.27 0.00 6023.07 ## 7444.83 0 -4348.71 9463.70 69.40 5.99 . 9600 00 . 64 33 245.12 5049.15 5101.45 -3333.54 -6739.66 5970934.73 364394.87 0.00 6097.46 ## 7534.96 0 -4399.60 9563.70 69.41 5.99 . 9700 00 . 64 33 245.12 5092.47 5144.77 -3371.45 -6821.42 5970898.23 364312.47 0.00 6171.85 ## 7625.09 0 -4450.48 9663.70 69.41 6.00 . 9800 00 . 64 33 245.12 ~ 5135.79 5188.09 -3409.37 -6903.19 5970861.74 364230.07 0.00 6246.24 ## 7715.21 0 -4501.36 9763.70 69.42 6.01 . 00 9900 . 64 33 245.12 5179.12 5231.42 -3447.28 -6984.95 5970825.24 364147.67 0.00 6320.63 ## 7805.34 0 -4552.25 9863.70 69.43 6.01 . 00 10000 . 64 33 245.12 5222.44 5274.74 -3485.20 -7066.72 5970788.75 364065.27 0.00 6395.02 ## 7895.47 0 -4603.13 9963.70 69.44 6.02 . 07 0022 . 64 33 245.12 5232.00 5284.30 -3493.56 -7084.76 5970780.70 364047.09 0.00 6411.44 ## 7915.36 0 -4614.36 9985.77 Albian 97 69.45 6.02 . 101 .00 . 64.33 245.12 5265.76 5318.06 -3523.11 -7148.49 5970752.25 363982.87 0.00 6469.41 ## 7985.60 0 -4654.01 10063.70 69.46 6.02 0 00 64 33 245.12 5309.09 5361.39 -3561.03 -7230.25 5970715.76 363900.47 0.00 6543.81 ## 8075.73 0 -4704.90 10163.70 69.46 6.03 . 00 . 64 33 245.12 5352.41 5404.71 -3598.94 -7312.02 5970679.27 363818.07 0.00 6618.20 ## 8165.86 0 -4755.78 10263.70 69.47 6.03 . .~..1•B~p0 00 . 64 33 245.12 5395.73 5448.03 -3636.86 -7393.78 5970642.77 363735.67 0.00 6692.59 ## 8255.98 0 -4806.66 10363.70 69.48 6.04 . 00 . 64 33 245.12 5439.05 5491.35 -3674.77 -7475.55 5970606.28 363653.27 0.00 6766.98 ## 8346.11 0 -4857.55 10463.70 69.49 6.04 . 00 0 0 . 64 33 245.12 5482.38 5534.68 -3712.69 -7557.31 5970569.78 363570.87 0.00 6841.37 ## 8436.24 0 -4908.43 10563.70 69.50 6.05 . 10 00 . 64 33 245.12 5525.70 5578.00 -3750.60 -7639.08 5970533.29 363488.47 0.00 6915.76 ## 8526.37 0 -4959.31 10663.70 69.50 6.06 . 00.00 . 64.33 245.12 5569.02 5621.32 -3788.52 -7720.84 5970496.79 363406.07 0.00 6990.15 ## 8616.50 0 -5010.20 10763.70 69.51 6.06 00 10900 64 33 245.12 5612.35 5664.65 -3826.43 -7802.61 5970460.30 363323.67 0.00 7064.54 ## 8706.63 0 -5061.08 10863.70 69.52 6.07 . .00 . 64.33 245.12 5655.67 5707.97 -3864.35 -7884.37 5970423.80 363241.27 0.00 7138.93 ## 8796.75 0 -5111.96 10963.70 69.53 6.07 00 64 33 245.12 5698.99 5751.29 -3902.27 -7966.14 5970387.31 363158.87 0.00 7213.32 ## 8886.88 0 -5162.85 11063.70 69.54 6.08 . 11200 00 . 64 33 245.12 5742.31 5794.61 -3940.18 -8047.90 5970350.81 363076.47 0.00 7287.72 ## 8977.01 0 -5213.73 11163.70 69.54 6.08 . 50 05 . 64 33 245 12 00 5764 5816 30 16 -3959 -8088.83 5970332.55 363035.22 0.00 7324.95 ## 9022.12 0 -5239.20 11213.75 Albian 96 69.55 6.08 . 112 11300 00 . 64 33 . 245.12 . 5785.64 . 5837.94 . -3978.10 -8129.67 5970314.32 362994.07 0.00 7362.11 ## 9067.14 0 -5264.61 11263.70 69.56 6.09 . 11400 00 . 64 33 245.12 5828.96 5881.26 -4016.01 -8211.43 5970277.82 362911.67 0.00 7436.50 ## 9157.27 0 -5315.50 11363.70 69.57 6.09 . 11500 00 . 64 33 245.12 5872.28 5924.58 -4053.93 -8293.20 5970241.33 362829.27 0.00 7510.89 ## 9247.40 0 -5366.38 11463.70 69.58 6.10 . 11600 00 . 64 33 245.12 5915.61 5967.91 -4091.84 -8374.96 5970204.83 362746.86 0.00 7585.28 ## 9337.52 0 -5417.26 11563.70 69.58 6.10 . 00 11700 . 64 33 245.12 5958.93 6011.23 -4129.76 -8456.73 5970168.34 362664.47 0.00 7659.67 ## 9427.65 0 -5468.15 11663.70 69.59 6.11 . 00 11800 . 33 64 245.12 6002.25 6054.55 -4167.67 -8538.49 5970131.85 362582.06 0.00 7734.06 ## 9517.78 0 -5519.03 11763.70 69.60 6.11 . 11900 00 . 64 33 245.12 6045.58 6097.88 -4205.59 -8620.26 5970095.35 362499.66 0.00 7808.45 ## 9607.91 0 -5569.91 11863.70 69.61 6.12 . 12000 00 . 64 33 245.12 6088.90 6141.20 -4243.50 -8702.03 5970058.86 362417.26 0.00 7882.84 ## 9698.04 0 -5620.80 11963.70 69.62 6.12 . 12100 00 . 64 33 245.12 6132.22 6184.52 -4281.42 -8783.79 5970022.36 362334.86 0.00 7957.23 ## 9788.17 0 -5671.68 12063.70 69.63 6.12 . 12200 00 . 64 33 245.12 6175.54 6227.84 -4319.33 -8865.56 5969985.87 362252.46 0.00 8031.63 ## 9878.30 0 -5722.56 12163.70 69.63 6.13 . 12300 00 . 64 33 245.12 6218.87 6271.17 -4357.25 -8947.32 5969949.37 362170.06 0.00 8106.02 ## 9968.42 0 -5773.44 12263.70 69.64 6.13 . 12400 00 . 64 33 245.12 6262.19 6314.49 -4395.16 -9029.09 5969912.88 362087.66 0.00 8180.41 ## 10058.55 0 -5824.33 12363.70 69.65 6.14 . 12500 00 . 64 33 245.12 6305.51 6357.81 -4433.08 -9110.85 5969876.38 362005.26 0.00 8254.80 ## 10148.68 0 -5875.21 12463.70 69.66 6.14 . 12600 00 . 50 64 247.27 6348.70 6401.00 -4469.48 -9193.37 5969841.42 361922.14 1.95 8330.18 ## 10238.87 85 -5924.72 12563.70 71.60 6.16 . 12700 00 . 64 71 249.41 6391.59 6443.89 -4502.81 -9277.32 5969809.54 361837.63 1.95 8407.49 ## 10329.21 84 -5971.45 12663.70 73.55 6.18 . 12800 00 . 64 95 251.55 6434.12 6486.42 -4533.05 -9362.62 5969780.78 361751.83 1.95 8486.63 ## 10419.72 83 -6015.35 12763.70 75.50 6.19 . 12900 00 . 65.22 253.67 6476.26 6528.56 -4560.16 -9449.16 5969755.18 361664.84 1.95 8567.51 ## 10510.41 83 -6056.35 12863.70 77.44 6.21 . 13000 00 65 52 255.79 6517.94 6570.24 -4584.09 -9536.84 5969732.76 361576.77 1.95 8650.04 ## 10601.31 82 -6094.43 12963.70 79.39 6.22 . 13100.00 . 65.84 257.89 6559.13 6611.43 -4604.84 -9625.57 5969713.55 361487.71 1.95 8734.13 ## 10692.43 81 -6129.52 13063.70 81.33 6.24 13200 00 66 20 259.99 6599.77 6652.07 -4622.36 -9715.23 5969697.58 361397.76 1.95 8819.68 ## 10783.80 80 -6161.60 13163.70 83.28 6.25 . 13300.00 . 66.58 262.07 6639.83 6692.13 -4636.65 -9805.74 5969684.85 361307.03 1.95 8906.58 ## 10875.43 79 -6190.62 13263.70 85.23 6.27 (CD2-75wp09.xls) Page 3 of 6 4/17/2008 3:29 PM CD2-75wp09 Report Meas. Inc]. TRUE Subsea RKB Local ASP or Grid Dogleg Original ie ao~¢w~uuoa um~ Tool Dist from Drilled l „n^~on•. DDI Depth (ft) Angle (deg) Azi. (deg) TVD (ft) TVD (ft) N(+)/S(-) (ft) E(+)/W(-) (ft) N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (7~ Severity (°/100 ft) VS(279°) (R) (3 (ft) 21046 (k) Face (deg) VS Plane (ft) Distance (ft) Comments 0 11 !! I l)~.~~) 7.0~ i,oo 13400.00 67.00 264.14 6679.24 6731.54 -4647.69 -9896.97 5969675.40 361215.63 1.95 8994.75 ## 10967.34 78 -6216.56 13363.70 87.18 6.28 13500.00 67.43 266.19 6717.97 6770.27 -4655.46 -9988.83 5969669.21 361123.65 1.95 9084.07 ## 11059.54 77 -6239.37 13463.70 89.11 6.29 13600.00 67.90 268.23 6755.98 6808.28 -4659.95 -10081.22 5969666.32 361031.21 1.95 9174.45 ## 11152.03 77 -6259.04 13563.70 91.06 6.31 13700.00 68.39 270.26 6793.21 6845.51 -4661.17 -10174.01 5969666.70 360938.41 1.95 9265.77 ## 11244.85 76 -6275.55 13663.70 93.01 6.32 13800.00 68.90 272.28 6829.62 6881.92 -4659.10 -10267.12 5969670,38 360845.36 1.95 9357.94 ## 11337.98 75 -6288.86 13763.70 94.96 6.33 13899.47 69.44 274.27 6865.00 6917.30 -4653.78 -10359.93 5969677.29 360752.66 1.95 9450.36 ## 11430.95 74 -6298.93 13863.17 HRZ 96.89 6.35 13900.00 69.44 274.28 6865.18 6917.48 -4653.75 -10360.42 5969677.34 360752.17 1.95 9450.85 ## 11431.45 74 -6298.98 13863.70 96.90 6.35 14000.00 70.00 276.27 6899.85 6952.15 -4645.12 -10453.82 5969687.57 360658.94 1.95 9544.39 ## 11525.25 74 -6305.88 13963.70 98.85 6.36 14100.00 70.58 278.24 6933.57 6985.87 -4633.24 -10547.20 5969701.07 360565.78 1.95 9638.46 ## 11619.39 73 -6309.56 14063.70 100.80 6.37 14200.00 71.19 280.20 6966.32 7018.62 -4618.10 -10640.46 5969717.81 360472.80 1.95 9732.94 ## 11713.87 72 -6310.01 14163.70 102.75 6.39 14300.00 71.81 282.14 6998.06 7050.36 -4599.73 -10733.49 5969737.78 360380.11 1.95 9827.72 ## 11808.71 72 -6307.24 14263.70 104.69 6.40 14371.16 72.27 283.51 7020.00 7072.30 -4584.71 -10799.49 5969753.94 360314.39 1.95 9895.30 ## 11876.40 71 -6303.31 14334.86 Base HRZ 106.07 6.41 14400.00 72.45 284.07 7028.74 7081.04 -4578.15 -10826.19 5969760.95 360287.81 1.95 9922.70 ## 11903.88 71 -6301.25 14363.70 106.63 6.41 14500.00 73.12 285.98 7058.34 7110.64 -4553.39 -10918.43 5969787.31 360196.01 1.95 10017.77 ## 11999.40 70 -6292.04 14463.70 108.58 6.42 14530.00 73.32 286.56 7067.00 7119.30 -4545.34 -10946.01 5969795.83 360168.58 1.95 10046.30 ## 12028.13 70 -6288.65 14493.70 K-1 Marker 109.17 6.q3 14600.00 73.80 287.89 7086.81 7139.11 -4525.46 -11010.13 5969816.81 360104.82 ].95 10112.82 ## 12095.26 70 -6279.62 14563.70 110.53 6.44 14677.16 74.33 289.34 7108.00 7160.30 -4501.78 -11080.44 5969841.70 360034.93 1.95 10186.07 ## 12169.45 69 -6267.86 14640.86 Ku aruk Fm 112.02 6.45 700.00 74.49 289.78 7114.14 7166.44 -4494.41 -11101.17 5969849.42 360014.33 1.95 10207.74 ## 12191.43 69 -6264.01 14663.70 112.47 6.45 4800.00 75.20 291.65 7140.28 7192.58 -4460.27 -11191.45 5969885.11 359924.66 1.95 10302.41 ## 12287.98 69 -6245.23 14763.70 114.41 6.46 900.00 75.93 293.51 7165.20 7217.50 -4423.08 -11280.86 5969923.84 359835.91 1.95 10396.73 ## 12384.82 68 -6223.30 14863.70 116.36 6.47 4911.55 76.02 293.73 7168.00 7220.30 -4418.59 -11291.13 5969928.50 359825.73 1.95 10407.60 ## 12396.02 68 -6220.57 14875.25 LCU-Miluveach 116.59 6.47 5000.00 76.67 295.37 7188.88 7241.18 •4382.88 -11369.31 5969965.55 359748.18 1.95 10490.60 ## 12481.98 68 -6198.24 14963.70 118.31 6.49 100.00 77.43 297.21 7211.29 7263.59 -4339.73 -11456.68 5970010.21 359661.57 1.95 10583.89 ## 12579.43 67 -6170.09 15063.70 120.26 6.50 200.00 78.20 299.04 7232.41 7284.71 -4293.65 -11542.88 5970057.76 359576.18 1.95 10676.51 ## 12677.18 67 -6138.87 15163.70 122.21 6.51 267.95 78.72 300.27 7246.00 7298.30 -4260.71 -11600.74 5970091.69 359518.91 1.95 10739.01 ## 12743.76 67 -6115.92 15231.65 Miluveach A 123.52 6.52 300.00 78.97 300.85 7252.20 7304.50 -4244.73 -11627.81 5970108.14 359492.12 1.95 10768.35 ## 12775.20 bb -6104.62 15263.70 124.14 6.52 5400.00 79.76 302.66 7270.65 7322.95 -4192.99 -11711.38 5970161.31 359409.47 1.95 10859.30 ## 12873.48 66 -6067.38 15363.70 126.09 6.53 13424.74 79.96 303.11 7275.00 7327.30 -4179.77 -11731.83 5970174.88 359389.25 1.95 10881.65 ## 12897.84 66 -6057.71 15388.44 AI ine D 126.57 6.54 5495.56 80.53 304.38 7287.00 7339.30 -4141.00 -11789.86 5970214.65 359331.90 1.95 10945.29 ## 12967.63 66 -6029.04 15459.26 AI ine C 127.95 6.54 15500.00 80.56 304.46 7287.73 7340.03 -4138.52 -11793.47 5970217.18 359328.33 1.95 10949.26 ## 12972.01 66 -6027.19 15463.70 128.03 6.54 15519.18 80.72 304.81 7290.85 7343.15 -4127.76 -11809.04 5970228.21 359312.94 1.95 10966.39 ## 12990.94 66 -6019.15 15482.88 128.41 6.55 15579.19 81.74 305.39 7300.00 7352.30 -4093.66 -11857.57 5970263.14 359265.02 1.95 11019.88 ## 13050.25 29 -5993.52 15542.89 AI ine B 129.58 6.55 15600.00 82.09 305.59 7302.93 7355.23 -4081.70 -11874.34 5970275.38 359248.46 1.95 11038.39 ## 13070.85 29 -5984.49 15563.70 129.99 6.56 15698.00 83.75 306.53 7315.00 7367.30 -4024.46 -11952.96 5970333.97 359170.84 1.95 11125.38 ## 13168.10 29 -5941.01 15661.70 7-5/8"x9-7/8" 13].89 6.57 15700.00 83.79 306.54 7315.22 7367.52 -4023.28 -11954.56 5970335.18 359169.27 1.95 11127.15 ## 13170.09 29 -5940.10 15663.70 131.93 6.57 15800.00 85.49 307.50 7324.56 7376.86 -3963.33 -12034.05 5970396.48 359090.83 1.95 11215.43 ## 13269.64 29 -5894.09 15763.70 133.88 6.5 15833.02 86.05 307.81 7327.00 7379.30 -3943.22 -12060.11 5970417.04 359065.12 1.95 11244.46 ## 13302.57 29 -5878.55 15796.72 AI ine A 134.52 6.58 15900.00 87.19 308.44 7330.95 7383.25 -3901.94 -12112.71 5970459.22 359013.24 1.95 11303.15 ## 13369.44 29 -5846.51 15863.70 135.82 6.59 16000.00 88.89 309.39 7334.37 7386.67 -3839.16 -12190.47 5970523.33 358936.58 1.95 11390.20 ## 13469.37 29 -5797.42 15963.70 137.77 6.60 16065.14 90.00 310.00 7335.00 7387.30 -3797.56 -12240.59 5970565.78 358887.19 1.95 11446.50 ## 13534.51 29 -5764.66 16028.84 CD2-75w 09 Heel 139.04 6.61 16100.00 90.02 311.22 7334.99 7387.29 -3774.87 -12267.06 5970588.92 358861.12 3.50 11476.34 ## 13569.37 89 -5746.65 16063.70 140.26 6.62 16200.00 90.07 314.72 7334.92 7387.22 -3706.72 -12340.22 5970658.32 358789.16 3.50 11559.74 ## 13669.37 89 -5691.50 16163.70 143.76 6.63 16300.00 90.12 318.22 7334.76 7387.06 -3634.23 -12409.08 5970731.98 358721.56 3.50 11639.62 ## 13769.37 89 -5631.36 16263.70 147.26 6.65 16400.00 90.17 321.72 7334.51 7386.81 -3557.68 -12473.39 5970809.63 358658.59 3.50 11715.68 ## 13869.37 89 -5566.46 16363.70 150.76 6.67 16500.00 90.22 325.22 7334.17 7386.47 -3477.33 -12532.91 5970890.98 358600.47 3.50 11787.63 ## 13969.37 89 -5497.04 16463.70 154.26 6.68 16600.00 90.27 328.72 7333.75 7386.05 -3393.51 -12587.41 5970975.73 358547.43 3.50 11855.21 ## 14069.37 89 -5423.35 16563.70 157.76 6.70 16700.00 90.31 332.22 7333.25 7385.55 -3306.52 -12636.69 5971063.55 358499.66 3.50 11918.17 ## 14169.37 89 -5345.68 16663.70 161.26 6.71 16712.57 90.32 332.66 7333.18 7385.48 -3295.37 -12642.51 5971074.80 358494.04 3.50 11925.75 ## 14181.94 89 -5335.65 16676.27 161.70 6.72 16800.00 90.32 332.66 7332.69 7384.99 -3217.71 -12682.66 5971153.13 358455.23 0.00 11978.16 ## 14269.37 0 -5265.68 16763.70 161.71 6.72 16900.00 90.32 332.66 7332.13 7384.43 -3128.89 -12728.59 5971242.73 358410.85 0.00 12038.11 ## 14369.36 0 -5185.64 16863.70 161.72 6.73 17000.00 90.32 332.66 7331.58 7383.88 -3040.06 -12774.52 5971332.33 358366.46 0.00 12098.06 ## 14469.36 0 -5105.61 16963.70 161.72 6.73 (CD2-75wp09.xls) Page 4 of 6 4/17/2008 3:29 PM CD2-75wp09 Report Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original ie nw<sw<uwan<~,«< Tool Disrfrom Drilled i~~!~r,:~~~. UII~ Depth (ft) Angle (deg) Azi. (deg) TVD (ft) TVD (ft) N(+)/S(-) (ft) E(+)/W(-) (fl) N(+)/S(-) Lat. (1~ E(+)/W(-) Dep. (X) Severity (°/100 ft) VS(279°) (ft) (3 (0) 21046 (ft) Face (deg VS Plane (ft) Distance (ft) Comments ~ 1 ~)?.?F) 7.04 1 ~!~!~ 17100.00 90.32 332.66 7331.02 7383.32 -2951.23 -12820.45 5971421.93 358322.08 0.00 12158.02 ## 14569.36 0 -5025.57 17063.70 161.73 6.74 17200.00 90.32 332.66 7330.46 7382.76 -2662.41 -12866.38 5971511.53 358277.69 0.00 12217.97 ## 14669.36 0 -4945.54 17163.70 161.74 6.74 17300.00 90.32 332.66 7329.91 7382.21 -2773.58 -11912.31 5971601.13 358233.30 0.00 12277.92 ## 14769.36 0 -4865.51 17263.70 161.75 6.75 17400.00 90.32 332.66 7329.35 7381.65 -2684.75 -12958.24 5971690.73 358188.92 0.00 12337.87 ## 14869.36 0 -4785.47 17363.70 161.76 6.75 17500.00 90.32 332.66 7328.80 7381.10 -2595.93 -13004.17 5971780.33 358144.53 0.00 12397.83 ## 14969.35 0 -4705.44 17463.70 161.76 6.76 17600.00 90.32 332.66 7328.24 7380.54 -2507.10 -13050.10 5971869.93 358100.15 0.00 12457.78 ## 15069.35 0 -4625.40 17563.70 161.77 6.76 17700.00 90.32 332.66 7327.68 7379.98 -2418.27 -13096.03 5971959.53 358055.76 0.00 12517.73 ## 15169.35 0 -4545.37 17663.70 161.78 6.77 17800.00 90.32 332.66 7327.13 7379.43 -2329.45 -13141.96 5972049.13 358011.38 0.00 12577.68 ## 15269.35 0 -4465.34 17763.70 161.79 6.78 17900.00 90.32 332.66 7326.57 7378.87 -2240.62 -13187.89 5972138.73 357966.99 0.00 12637.63 ## 15369.35 0 -4385.30 17863.70 161.80 6.78 18000.00 90.32 332.66 7326.02 7378.32 -2151.79 -13233.81 5972228.33 357921.61 0.00 12697.59 ## 15469.35 0 -4305.27 17963.70 161.81 6.79 18100.00 90.32 332.66 7325.46 7377.76 -2062.97 -13279.74 5972317.93 337878.22 0.00 12757.54 ## 15569.35 0 -4225.24 18063.70 161.81 6.79 18200.00 90.32 332.66 7324.90 7377.20 -1974.14 -13325.67 5972407.53 357833.84 0.00 12817.49 ## 15669.34 0 -4145.20 18163.70 161.82 6.80 18300.00 90.32 332.66 7324.35 7376.65 -1885.31 -13371.60 5972497.13 357789.45 0.00 12877.44 ## 15769.34 0 -4065.17 18263.70 161.83 6.80 18400.00 90.32 332.66 7323.79 7376.09 -1796.49 -13417.53 5972586.73 357745.07 0.00 12937.40 ## 15869.34 0 -3985.13 18363.70 161.84 6.81 18500.00 90.32 332.66 7323.23 7375.53 -1707.66 -13463.46 5972676.33 357700.68 0.00 12997.35 ## 15969.34 0 -3905.10 18463.70 161.85 6.81 18600.00 90.32 332.66 7322.68 7374.98 -1618.83 -13509.39 5972765.93 357656.30 0.00 13057.30 ## 16069.34 0 -3825.07 18563.70 161.85 6.82 1 0.00 90.32 332.66 7322.12 7374.42 -1530.01 -13555.32 5972855.53 357611.91 0.00 13117.25 ## 16169.34 0 -3745.03 18663.70 161.86 6.82 00.00 90.32 332.66 7321.57 7373.87 -1441.18 -13601.25 5972945.13 357567.53 0.00 13177.21 ## 16269.33 0 -3665.00 18763.70 161.87 6.83 18 0.00 90.32 332.66 7321.01 7373.31 -1352.35 -13647.18 5973034.73 357523.14 0.00 13237.16 ## 16369.33 0 -3584.97 18863.70 161.88 6.83 9000.00 90.32 332.66 7320.45 7372.75 -1263.52 -13693.11 5973124.33 357478.76 0.00 13297.11 ## 16469.33 0 -3504.93 18963.70 161.89 6.84 100.00 90.32 332.66 7319.90 7372.20 -1174.70 -13739.04 5973213.93 357434.37 0.00 13357.06 ## 16369.33 0 -3424.90 19063.70 161.89 6.84 1 00.00 90.32 332.66 7319.34 7371.64 -1085.87 -13784.97 5973303.52 357389.98 0.00 13417.01 ## 16669.33 0 -3344.86 19163.70 161.90 6.85 00.00 90.32 332.66 7318.79 7371.09 -997.04 -13830.89 5973393.12 357345.60 0.00 13476.97 ## 16769.33 0 -3264.83 19263.70 161.91 6.85 00.00 90.32 332.66 7318.23 7370.53 -908.22 -13876.82 5973482.72 357301.21 0.00 13536.92 ## 16869.33 0 -3184.80 19363.70 161.92 6.86 00.00 90.32 332.66 7317.67 7369.97 -819.39 -13922.75 5973572.32 357256.83 0.00 13596.87 ## 16969.32 0 -3104.76 19463.70 161.93 6.86 00.00 90.32 332.66 7317.12 7369.42 -730.56 -13968.68 5973661.92 357212.44 0.00 13656.82 ## 17069.32 0 -3024.73 19563.70 161.93 6.87 19700.00 19800.00 90.32 90.32 332.66 332.66 7316.56 7316.00 7368.86 7368.30 -641.74 -552.91 -14014.61 -14060.54 5973751.52 5973841.12 357168.06 357123.67 0.00 0.00 13716.78 13776.73 ## ## 17169.32 17269.32 0 0 -2944.69 -2864.66 19663.70 19763.70 161.94 161.95 6.87 6.88 19900.00 90.32 332.66 7315.45 7367.75 -464.08 -14106.47 5973930.72 357079.29 0.00 13836.68 ## 17369.32 0 -2784.63 19863.70 161.96 6.88 20000.00 90.32 332.66 7314.89 7367.19 -375.26 -14152.40 5974020.32 357034.90 0.00 13896.63 ## 17469.32 0 -2704.59 19963.70 161.97 6.89 20100.00 90.32 332.66 7314.34 7366.64 -286.43 -14198.33 5974109.92 356990.52 0.00 13956.59 ## 17569.31 0 -2624.56 20063.70 161.98 6.89 20200.00 90.32 332.66 7313.78 7366.08 -197.60 -14244.26 5974199.52 356946.13 0.00 14016.54 ## 17669.31 0 -2544.53 20163.70 161.98 6.59 20300.00 90.32 332.66 7313.22 7365.52 -108.78 -14290.19 5974289.12 356901.75 0.00 14076.49 ## 17769.31 0 -2464.49 20263.70 161.99 6.90 20400.00 90.32 332.66 7312.67 7364.97 -19.95 -14336.12 5974378.72 356857.36 0.00 14136.44 ## 17869.31. 0 -2384.46 20363.70 162.00 6.90 20500.00 90.32 332.66 7312.11 7364.41 68.88 -14382.05 5974468.32 356812.98 0.00 14196.39 ## 17969.31 0 -2304.41 20463.70 162.01 6.9 20600.00 90.32 332.66 7311.55 7363.85 157.70 -14427.98 5974557.92 356768.59 0.00 14256.35 ## 18069.31 0 -2224.39 20563.70 162.02 6.91 20700.00 90.32 332.66 7311.00 7363.30 246.53 -14473.90 5974647.52 356724.21 0.00 14316.30 ## 18169.30 0 -2144.36 20663.70 162.02 6.92 20800.00 90.32 332.66 7310.44 7362.74 335.36 -14519.83 5974737.12 356679.82 0.00 14376.25 ## 18269.30 0 -2064.32 20763.70 162.03 6.92 20900.00 90.32 332.66 7309.89 7362.19 424.18 -14565.76 5974826.72 356635.43 0.00 14436.20 ## 18369.30 0 -1984.29 20863.70 162.04 6.93 21000.00 90.32 332.66 7309.33 7361.63 513.01 -14611.69 5974916.32 356591.05 0.00 14496.16 ## 18469.30 0 -1904.25 20963.70 162.05 6.93 21100.00 90.32 332.66 7308.77 7361.07 601.84 -14657.62 5975005.92 356546.66 0.00 14556.11 !k# 18569.30 0 -1824.22 21063.70 162.06 6.94 21200.00 90.32 332.66 7308.22 7360.52 690.66 -14703.55 5975095.52 356502.28 0.00 14616.06 ## 18669.30 0 -1744.19 21163.70 162.06 6.94 21300.00 90.32 332.66 7307.66 7359.96 779.49 -14749.48 5975185.12 356457.89 0.00 14676.01 ## 18769.30 0 -1664.15 21263.70 162.07 6.94 21400.00 90.32 332.66 7307.11 7359.41 868.32 -14795.41 5975274.72 356413.51 0.00 14735.97 ## 18869.29 0 -1584.12 21363.70 162.08 6.95 21500.00 90.32 332.66 7306.55 7358.85 957.14 -14841.34 5975364.32 356369.12 0.00 14795.92 ## 18969.29 0 -1504.09 21463.70 162.09 6.95 21600.00 90.32 332.66 7305.99 7358.29 1045.97 -14887.27 5975453.92 356324.74 0.00 14855.87 ## 19069.29 0 -1424.05 21563.70 162.10 6.96 21700.00 90.32 332.66 7305.44 7357.74 1134.80 -14933.20 5975543.52 356280.35 0.00 14915.82 ## 19169.29 0 -1344.02 21663.70 162.10 6.96 21800.00 90.32 332.66 7304.88. 7357.18 1223.62 -14979.13 5975633.12 356235.97 0.00 14975.77 ## 19269.29 0 -1263.98 21763.70 162.11 6.97 21900.00 90.32 332.66 7304.32 7356.62 1312.45 -15025.06 5975722.72 356191.58 0.00 15035.73 ## 19369.29 0 -1183.95 21863.70 162.12 6.97 22000.00 90.32 332.66 7303.77 7356.07 1401.28 -15070.98 5975812.32 356147.20 0.00 15095.68 ## 19469.28 0 -1103.92 21963.70 162.13 6.97 22100.00 90.32 332.66 7303.21 7355.51 1490.11 -15116.91 5975901.91 356102.81 0.00 15155.63 ## 19569.28 0 -1023.88 22063.70 162.14 6.98 (CD2-75wp09.xls) Page 5 of 6 4/17/2008 3:29 PM CD2-75wp09 Report Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original ie ae~y w<on«o<v=mp< Tool Dist Gom Drilled ,x, ~. ,u~~sn.c 1 DUI Depth (R) Angle (deg) Azi. (deg) TVD (ft) TVD (Pt) N(+)/S(-) (ft) E(+)/W(-) (ft) N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (279°) (ft) (3 (ft) 21046 (ft) face (deg) VS Plane (ft) Distance (ft) Comments 0 11 `` I V ~~'..? l1 7.04 Loo 22200.00 90.32 332.66 7302.66 7334.96 1578.93 -13162.84 5975991.51 336038.43 0.00 13213.38 ## 19669.28 0 -943.83 22163.70 162.15 6.98 22300.00 90.32 332.66 7302.10 7334.40 1667.76 -13208.77 5976081.11 336014.04 0.00 13273.34 ## 19769.28 0 -863.82 22263.70 162.15 6.99 22400.00 90.32 332.66 7301.54 7333.84 1756.59 -13234.70 5976170.71 333969.63 0.00 13333.49 ## 19869.28 0 -783.78 22363.70 162.16 6.99 22300.00 90.32 332.66 7300.99 7333.29 1845.41 -13300.63 5976260.31 333923.27 0.00 13393.44 ## 19969.28 0 -703.73 22463.70 162.17 7.00 22600.00 90.32 332.66 7300.43 7332.73 1934.24 -13346.36 5976349.91 333880.88 0.00 13433.39 ## 20069.28 0 -623.71 22563.70 162.18 7.00 22700.00 90.32 332.66 7299.88 7332.18 2023.07 -13392.49 5976439.51 333836.30 0.00 13313.33 ## 20169.27 0 -343,68 22663.70 162.19 7.00 22800.00 90.32 332.66 7299.32 7331.62 2111.89 -13438.42 5976529.11 333792.11 0.00 13373.30 ## 20269.27 0 -463.63 22763.70 162.19 7.01 22900.00 90.32 332.66 7298.76 7331.06 2200.72 -13484.33 5976618.71 333747.73 0.00 13633.23 ## 20369.27 0 -383.61 22863.70 162.20 7.01 23000.00 90.32 332.66 7298.21 7330.31 2289.55 -13330.28 5976708.31 333703.34 0.00 13693.20 ## 20469.27 0 -303.38 22963.70 162.21 7.02 23100.00 90.32 332.66 7297.65 7349.93 2378.37 -13376.21 5976797.91 333638.96 0.00 13733.13 ## 20369.27 0 -223.34 23063.70 162.22 7.02 23200.00 90.32 332.66 7297.09 7349.39 2467.20 -13622.14 5976887.51 333614.37 0.00 13813.11 ## 20669.27 0 -143.31 23163.70 162.23 7.02 23300.00 90.32 332.66 7296.54 7348.84 2556.03 -13668.07 5976977.11 333370.19 0.00 13873.06 ## 20769.26 0 -63.48 23263.70 162.23 7.03 23400.00 90.32 332.66 7295.98 7348.28 2644.85 -13713.99 5977066.71 333323.80 0.00 13933.01 ## 20869.26 0 16.36 23363.70 162.24 7.03 23300.00 90.32 332.66 7295.43 7347.73 2733.68 -13739.92 5977156.31 333481.42 0.00 13994.96 ## 20969.26 0 96.39 23463.70 162.25 7.04 • 23376.39 90.32 332.66 7295.00 7347.30 2801.71 -13793.10 5977224.93 333447.42 0.00 16040.88 ## 21043.83 0 137.89 23540.29 4-I/2" x 6-3/4" - C 162.26 7.04 (CD2-75wp09.xls) Page 6 of 6 4/17/2008 3:29 PM Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-75 Wellbore: Plan: CD2-75 Design: GD2-75wp09 Formations ConocoPhillips Standard Proposal Report Local Co-ordinate Referenc®: Well Plan: CD2-75 ND Reference: Planned D19 for AW @ 52.30ft (Doyon 19 (36.3 MD Reference: Planned D19 for AW @ 52.30ft (Doyon 19 (36.31 North Reference: True Survey Catcutation Method: Minimum Curvature Measured Vertical Vertical Depth Depth Depth SS (ft) (ft) ft ttlame 15,267.95 7,298.30 Miluveach A 15,833.02 7,379.30 Alpine A 14,677.16 7,160.30 Kuparuk Fm 14,530.00 7,119.30 K-1 Marker 11,250.05 5,816.30 Albian 96 4,239.91 2,779.30 C-20 10,022.07 5,284.30 Albian 97 7,127.53 4,030.30 Basal K-3 7,388.36 4,143.30 Basal K-2 7,194.47 4,059.30 K-2 Marker 15,495.56 7,339.30 Alpine C 15,579.19 7,352.30 Alpine B 14,371.16 7,072.30 Base HRZ 6,675.11 3,834.30 K-3 Marker 15,424.74 7,327.30 Alpine D 3,353.54 2,395.30 C-30 14,911.55 7,220.30 LCU-Miluveach 13,899.47 6,917.30 HRZ Dip pip Direction Lithology (~) (~) 0.00 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI~S +FJ-W (ft) (ft) (ft) (ft) :Comment I 300.00 300.00 0.00 0.00 KOP: 2.3 DLS 4/11/2008 11:38:22AM Page 10 COMPASS 2003.16 Build 42F .-,..... r-.- ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad Plan: CD2-75 Plan: CD2-75 CD2-75wp09 :Sp~rrry Drillnc„~ Services Clearance Summary Anticollision Report 11 April, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-75 -Plan: CD2-75 -CD2-75wp09 Well Coordinates: 5,973,897.81 N, 1,511,223.21E (70° 20' 14.13" N, 151° 02' 53.93" W) Datum Height: Planned D19 for AW ~ 52.30ft (Doyon 19 (36.3+16)) Scan Range: 0.00 to 23,576.59 ft. Measured Depth. Scan Radius is 2,554.03 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLiBURT~N Sperry Drilling 8~rvic®s i 11'd3, Apnl 11 2008 ConocoPhillips Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-75 Parent Well: No wellbore data is available Wellbore: Plan: CD2-75 REFERENCEINFORMATION Co-ordinate (N/E) Reference: Well Plan CD2-75. True P1onh Vertical (TVD) Reference: Planned 019 for AW /t"D 52.300 (Doyon 19 (36.3+1 Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Planned 019 for AW ~ 52.30ft (Doyon 19 (36.3+1 Dz-470wp0 D2-0E -90 / CD2-75wp09 36.30 To 23576.59 Interpaadon Method: MD, mtervai: zs.oo Maximum Range: 3550.01 Scan McMOd: Trav. CNinder North Error SUrtace: Elliptical Conic WaminO Method: Rules Based GLOBAL FILTER APPLIED: All wellpaths within 100'+ 100/1000 of reference 6l'RV NY PROGR.\\I zuuA-0d-uTW:W:oo eal:daled: vex ver~ie.: urpm Pr~~m D.pm'r~~ , ,ev/F'lan T~wi 3d.3o ]oou.oo cDZas..pW 0'i=.: ruz-nl cR.<a~RacS ]000.00 23~]6.5'J ('D2-'/chp09 (Plv~:fD2-]5) \D\MIN'R-4K-CA45C Dzaawpo Geodetic System: US State Plane 1983 Datum: North American Datum 1 Ellipsoitl: GRS 1980 Zone: Alaska Zone 4 Critical Issues: -90 / _1 90 From Colour To MD 36 250 2500 3000 9000 10000 250 soo 3000 3500 10000 12000 500 750 3500 4000 12000 14000 750 1000 4000 4500 14000 16000 1000 1250 4500 5000 16000 18000 1250 1500 5000 6000 18000 20000 1500 1750 6000 7000 20000 25000 1750 2000 7000 8000 2000 2500 8000 9000 0 / 360 -1ao / 1so -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation (50 fUin] SECTION DETAILS Sec MD Inc Azi TVD +N/S +E/-W DLeg TFace VSec Target 1 36.30 O.W O.W 36.30 O.W O.W O.W O.W O.W z 3W.W o.W o.W 3W.W o.W B.W o.W o.W o.W 3 SSO.W 5.75 230.W SJ9_58 -8.06 -9.60 2.30 230.W A.1J J YW.00 16.2J 23316 892.68 -4A.71 -62.3'J 3.W S.W 53.50 5 201X1.011 54.7J 233.26 1771.61 J23.57 -56J.50 3..50 O.W #86.90 6 25011.W 6J.33 2J5.12 2025.52 fi41.55 A3J.33 2.81] SO.W R15.70 7 1251X1.011 fiJ.33 245.12 6357.81 JJ33.U8 -9110.85 ILW O.ql A254.N11 8 15519.18 80.72 301.81 73J3.15 -II27.76 -118119.OJ 195 85.27 10966.39 9 16WS.IJ 'IO.W 310.W 7387.30 -379756 -12240.59 1.95 2`).39 11 JJ6.SU CD2-75wpU9 Hml 10 16712.57 90.32 332.66 7385A8 -3295.37 -1264251 3.50 A9.17 11925.75 HALLIBURTON ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-75 -CD2-75wp09 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-75 -Plan: CD2-75 -CD2-75wp09 Scan Range: 0.00 to 23,576.59 ft. Measured Depth. Scan Radius is 2,554.03 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad C~ CD2-05 -CD2-05 -CD2-05 2,738.76 390.88 2,738.76 343.45 3,400.00 8.241 Centre Distance Pass -Major Risk CD2-05 -CD2-05 -CD2-05 2,762.92 390.96 2,762.92 343.37 3,425.00 8.215 Clearance Factor Pass -Major Risk CD2-05 -CD2-05L1 -CD2-05L1 2,738.76 390.88 2,738.76 343.45 3,400.00 8.241 Centre Distance Pass -Major Risk ' CD2-05 -CD2-05L1 -CD2-05L1 2,762.92 390.96 2,762.92 343.37 3,425.00 8.215 Clearance Factor Pass -Major Risk ~'~ `~ \,.p .s CD2-30 -CD2-30 -CD2-30 2,049.69 384.52 2,049.69 351.11 2,550.00 11.508 Centre Distance Pass -Major Risk CD2-30 -CD2-30 -CD2-30 2,094.27 384.78 2,094.27 350.69 2,600.00 11.288 Clearance Factor Pass -Major Risk CD2-33 -CD2-33 -CD2-33 100.25 610.72 100.25 608.79 100.00 316.366 Centre Distance Pass -Major Risk ~"i CD2-33 -CD2-33 -CD2-33 7,763.45 643.78 7,763.45 393.35 8,775.00 2.571 Clearance Factor Pass -Major Risk CD2-33 -CD2-33A -CD2-33A 6,492.05 525.39 6,492.05 414.52 7,500.00 4.739 Clearance Factor Pass -Major Risk CD2-33 -CD2-33A -CD2-33A 6,821.75 513.34 6,821.75 416.78 7,850.00 5.316 Centre Distance Pass -Major Risk CD2-40 -CD2-40 -CD2-40 1,900.00 514.29 1,900.00 483.33 2,425.00 16.611 Centre Distance Pass -Major Risk CD2-40 -CD2-40 -CD2-40 1,929.20 514.40 1,929.20 483.09 2,450.00 16.429 Clearance Factor Pass -Major Risk CD2-40 -CD2-40PB1 -CD2-40PB1 1,900.00 514.29 1,900.00 483.33 2,425.00 16.611 Centre Distance Pass -Major Risk CD2-40 -CD2-40P61 -CD2-40P61 1,929.20 514.40 1,929.20 483.09 2,450.00 16.429 Clearance Factor Pass -Major Risk CD2-43 -CD2-43 -CD2-43 1,977.37 322.86 1,977.37 290.13 2,425.00 9.864 Centre Distance Pass -Major Risk CD2-43 -CD2-43 -CD2-43 2,000.00 323.04 2,000.00 290.01 2,450.00 9.780 Clearance Factor Pass -Major Risk CD2-43 -CD2-43PB1 -CD2-43PB1 1,977.37 322.86 1,977.37 290.13 2,425.00 9.864 Centre Distance Pass -Major Risk CD2-43 -CD2-43P61 -CD2-43PB1 2,000.00 323.04 2,000.00 290.01 2,450.00 9.780 Clearance Factor Pass -Major Risk CD2-43 -Prelim: CD2-43A-CD2-43Awp02 1,977.37 322.86 1,977.37 290.12 2,425.00 9.862 Centre Distance Pass -Major Risk CD2-43 -Prelim: CD2-43A -CD2-43Awp02 2,000.00 323.04 2,000.00 290.00 2,450.00 9.778 Clearance Factor Pass -Major Risk CD2-54 -CD2-54 -CD2-54 2,304.84 144.59 2,304.84 105.74 2,675.00 3.722 Centre Distance Pass -Major Risk CD2-54 -CD2-54 -CD2-54 2,352.12 144.94 2,352.12 105.28 2,725.00 3.655 Clearance Factor Pass -Major Risk CD2-54 -CD2-54L1 -CD2-54L1 2,304.84 144.59 2,304.84 105.74 2,675.00 3.722 Centre Distance Pass -Major Risk CD2-54 -CD2-54L1 -CD2-54L1 2,352.12 144.94 2,352.12 105.28 2,725.00 3.655 Clearance Factor Pass -Major Risk CD2-56 -CD2-56 -CD2-56 2,186.01 210.80 2,186.01 157.03 2,550.00 3.920 Centre Distance Pass -Major Risk CD2-56 -CD2-56 -CD2-56 2,231.86 211.40 2,231.86 156.20 2,600.00 3.830 Clearance Factor Pass -Major Risk CD2-56 -CD2-56L1 -CD2-56L1 2,186.01 210.80 2,186.01 156.98 2,550.00 3.917 Centre Distance Pass -Major Risk CD2-56 -CD2-56L1 -CD2-56L1 2,231.86 211.40 2,231.86 156.15 2,600.00 3.826 Clearance Factor Pass -Major Risk • 11 April, 2008 - 11:47 Page 2 of 6 COMPASS HALLIBURTON ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-75 -CD2-75wp09 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-75 -Plan: CD2-75 -CD2-75wp09 Scan Range: 0.00 to 23,576.59 ft. Measured Depth. Scan Radius is 2,554.03 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2-59 -CD2-59 -CD2-59 1,700.00 310.11 1,700.00 278.85 2,075.00 9.922 Centre Distance Pass -Major Risk CD2-59 -CD2-59 -CD2-59 1,773.29 310.83 1,773.29 276.35 2,175.00 9.016 Clearance Factor Pass -Major Risk CD2-59 -CD2-59PB1 -CD2-59P61 1,700.00 310.11 1,700.00 278.85 2,075.00 9.922 Centre Distance Pass -Major Risk CD2-59 -CD2-59PB1 -CD2-59PB1 1,773.29 310.83 1,773.29 276.35 2,175.00 9.016 Clearance Factor Pass -Major Risk CD2-72 -CD2-72 -CD2-72 47.97 60.05 47.97 58.85 50.00 50.018 Centre Distance Pass -Major Risk CD2-72 -CD2-72 -CD2-72 346.96 62.42 346.96 54.97 350.00 8.372 Clearance Factor Pass -Major Risk Plan: CD2-463 -Plan: CD2-463wp05 -CD2-463wp05 275.10 240.02 275.10 234.20 275.00 41.236 Centre Distance Pass -Major Risk "'~ Plan: CD2-463 -Plan: CD2-463wp05 -CD2-463wp05 323.22 240.21 323.22 233.33 325.00 34.933 Clearance Factor Pass -Major Risk Plan: CD2-464 -Plan: CD2-464 -CD2-464wp06 275.10 220.13 275.10 214.31 275.00 37.818 Centre Distance Pass -Major Risk Plan: CD2-464 -Plan: CD2-464 -CD2-464wp06 346.64 220.55 346.64 213.16 350.00 29.829 Clearance Factor Pass -Major Risk Plan: CD2-465 -Plan: CD2-465 -CD2-465wp02 275.10 199.96 275.10 194.14 275.00 34.353 Centre Distance Pass -Major Risk Plan: CD2-465 -Plan: CD2-465 -CD2-465wp02 486.87 201.85 486.87 191.35 500.00 19.234 Clearance Factor Pass -Major Risk Plan: CD2-466 -Plan: CD2-466 -CD2-466wp04 323.65 180.03 323.65 173.15 325.00 26.154 Centre Distance Pass -Major Risk i Plan: CD2-466 -Plan: CD2-466 -CD2-466wp04 394.17 180.78 394.17 172.34 400.00 21.416 Clearance Factor Pass -Major Risk Plan: CD2-467 -Plan: CD2-467 -CD2-467wp03 275.10 159.93 275.10 154.11 275.00 27.476 Centre Distance Pass -Major Risk Plan: CD2-467 -Plan: CD2-467 -CD2-467wp03 371.24 160.83 371.24 152.91 375.00 20.283 Clearance Factor Pass -Major Risk Plan: CD2-468 -Plan: CD2-468 -CD2-468wp02 585.74 136.71 585.74 124.08 600.00 10.822 Centre Distance Pass -Major Risk Plan: CD2-468 -Plan: CD2-468 -CD2-468wp02 937.05 142.30 937.05 122.05 975.00 7.028 Clearance Factor Pass -Major Risk Plan: CD2-469 -Plan: CD2-469 -CD2-469wp04 1,549.37 61.33 1,549.37 31.18 1,625.00 2.034 Centre Distance Pass -Major Risk Plan: CD2-469 -Plan: CD2-469 -CD2-469wp04 1,596.38 62.02 1,596.38 29.73 1,675.00 1.921 Clearance Factor Pass -Major Risk Plan: CD2-470 -Plan: CD2-470 -CD2-470wp03 275.10 100.10 275.10 94.28 275.00 17.198 Centre Distance Pass -Major Risk Plan: CD2-470 -Plan: CD2-470 -CD2-470wp03 7,622.72 232.77 7,622.72 77.29 8,975.00 1.497 Clearance Factor Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp01 275.10 80.03 275.10 74.21 275.00 13.748 Centre Distance Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp01 348.78 80.47 348.78 73.04 350.00 10.833 Clearance Factor Pass -Major Risk Plan: CD2-74 -Plan: CD2-74 -CD2-74wp02 300.00 20.00 300.00 13.64 300.00 3.144 Centre Distance Pass -Major Risk Plan: CD2-74 -Plan: CD2-74 -CD2-74wp02 374.48 20.95 374.48 12.97 375.00 2.625 Clearance Factor Pass -Major Risk CD4 Nanuq Pad CD4-07 -CD4-07 -CD4-07wp10 14,476.06 1,302.84 14,476.06 798.74 25,272.68 2.584 Clearance Factor Pass -Major Risk CD4-07 -CD4-07 -CD4-07 14,400.00 1,436.07 14,400.00 963.58 25,040.00 3.039 Clearance Factor Pass -Major Risk 11 April, 2008 - 11:47 Page 3 of 6 COMPASS HALLIBURTC~N ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-75 -CD2-75wp09 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-75 -Plan: CD2-75 -CD2-75wp09 Scan Range: 0.00 to 23,576.59 ft. Measured Depth. Scan Radius is 2,554.03 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft Plan: CD5 Alpine West Pad (original locatic Plan: AW-4A -Plan: AW-4A - AW-4Awp02 23,278.12 1,973.82 23,278.12 1,534.75 10,350.00 4.495 Centre Distance Pass -Major Risk Plan: AW-4A -Plan: AW-4A - AW-4Awp02 23,571.00 1,976.61 23,571.00 1,523.20 10,650.00 4.359 Clearance Factor Pass -Major Risk Plan: AW-4B -Plan: AW-46 - AW-4Bwp02 22,760.86 1,980.15 22,760.86 1,449.02 18,230.25 3.728 Clearance Factor Pass -Major Risk ..~ ~ Survey tool program ° r~ From To Survey/Plan Survey Tool (ft) (ft) 36.30 1,000.00 CD2-75wp09 CB-GYRO-SS 1,000.00 23,576.59 CD2-75wp09 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 April, 2008 - 11:47 Page 4 of 6 COMPASS Calculation Method: Minimum l:urvdW re / E°or5ystem: 15CW5A Pro'ect: Western North Slo e ConocoPhillips swnMemod: rrae.cytinaerNOrtn ~ p Ertor SUrfxe: Elliptlcal COnlc CD2 d Site: CD2 Alpine Pad B 75 09 Waming Metlr°,: Rules ase wp - Geotletlc Oahrm: NoM American Datum 7983 Well: Plan: CD2-75 Magnetic Model: BGGM309] Wellbore: Plan: CD2-75 Quarter Mile View RKH planned 019 for AW ~a 52.308 (DOyon 19 (36.3-16)) CD2-75wpU9 F.utnig/ASP X'. !51122J.21 _-_ ~^ ~~ Q ~ $ y~ '~ 6 ~r GO2 ~ ~ GOZ 1~ GO20 02 ~2 _ G it GO Ay ,~SP Z, P 1 02 5000 - GO• A ' 69 GO2' ti O^; O G Z2 O~• I ti ~-. G C Q 9 2500 Go • ~ N z3 ~ ~ O o ~ r N 9Q y 2 v ~' GO~ 1 .}. A~, ~ 0 _ O 5 ~ G G O Z ~ GO1 GO~~S ~ ~ L - 2500 - 50 GO2 t ~ a9 -5000 GOa 0'1 .off' a as O~'• GO2~ o w Ga 1 ,ye Gotta 2'a~ GozyS .~~ - w ?-sops' ~~ `~~.~ 500 -5000 -2500 -22500 -20000 -17500 -15000 -12500 -10000 West(-)/East(+) (2500 ft/in) ~•~ V d• Operolor Pieta: Wek M9: sadaa. laaaxaa x: r: Comments: s d U) D O U t N 1 7 N T ConocoPhi9ipa(Aloaka)Inc. -W NS Wedern Nwlh Nepe C p1.)Swp99 MN/A tsnzzl.m n snleyzet n POOL: CD2-75wp09 Plan: 16065' to 23576.59' MD CD2-59: 15556' to 20027' MD CD2-54L1: 14178' to 18250' MD CD4-07: 17700' to 25040' MD CD2-33: 7270' to 7350' TVDss Grb COn.clbn: 0.99 lab NO: RN/A Magn.Nc D.cNnalbrv 33.11 APE No: MN/A pp: 80.69 AM No: MN/A Deglsq psr 10p ft SyAam (LVD)bMnnce: Mean :ea level Original VS Plane: 279.49 xaa.ntwx: nan: coz.)3 View VS Plane: 279.49 RNe xNgm: sz.w x unx Srdem: Saclion (VS) R.lerencs: 51ot Plan ~jew G `~~ 5979800 5978800 5977800 5976800 5975800 5974800 5973800 5972800 5971800 5970800 5969800 5968800 5967800 5966800 7600 Combo Preview Page 1 of 1 (CD2-75wp09 Toolbox.xls) 4/17/2008 10:15 AM g g o o °0 0 0 °o °O W P O N M V ~ `o Vertical Section along "View VS Plane"^ TRANSMITTAL LETTER CHECKLIST WELL NAME C~~ ~ Z- ~ ~S- PTD# ~ U ~ '-U~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD. ~~ -~ ~1~~-~`' POOL: ~- 4~'~- ~a Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS} TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after f Comaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of s,~ch water well testing ro ram. Rev: 1/1(/2008 WELE PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL -120100 Well Name: COLVILLE RN UNIT CD2.75 Program DEV Well bore seg ^ PTD#:2080640 Comparry rONOCOPHILLIPS ALASKA INC Initial ClasslType DEV I PEND GeoArea Unit 50360 OnlOff Shore -~ Annular Disposal ^ Administration ' 1 Pem]iti'aa aftache~- - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Surface location in A))L 380075;-passes thtu ADh 387207, t°p-plod- int_& TD on ASRC -Fes acreage, - _ _ _ _ _ _ 3 Uniqueweltnameandnumbet_.. ---- -- - ---- - --- --Yes --- - ---- - ----- ---- -- - -- - ---- - 4 Well located in a_dafirn'dpDCl----------------------------- ---------Yes- ------COLVILLE_RIVER,ALPINE_Olt.-12010Q,govemed by CO 448A.-.----------.--------------- 5 V+leli located proper distance irorrt dn)iing unitboundary_ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ Closest approach is ~3ti00' from CRIJ boundary and ~80tY from Alpine PA boundary.- _ _ _ - - . _ _ _ _ _ _ 6 Wfllllacatedproperd[stanceftomGthelwgl)s------------------- -------Yes- ------"1.800UomCD2.58.----------------------------------------------------- 7 Sufficient acreage available in_drllling unR - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 If deviated,is_weilboreplatincluded-- ---- --- -- -- - --- Yes -- - -- - -- - -- ----- --- --- - -- ---- I I 9 Operatoron~reffedadParty ---- ---- ~ -- -- --- Yes- ---- -- --- - ~-- ------ -- - -- - -- ---- I 1D Operatothas_approprialebondinforce- --- -- - ----- ---- Yes. -- ----- ---- ------ ----- - - -- - --- ~~ 11 Permitcanbeissuedwithoutcollservaticncrdar ----- - --- -- ---Yes ----- ----- -- - --- ------ --- -- - - ---- - --- Appr Date 12 P®tmitcanbeiasuedwith2utadmiraistrattve_approval------.-------- --------Yas- --------------------------------------------------------------- SFD 4l22l20D8 13 Canperm)t-beaPRro+'~lbeforal5ilaywak --- - -- - --- --- -- Yes -- - ------ - ---- -- - ----- ---- - -- -- --- --- 14 Weli_ktcatedwithinareaa~strataauthorizedby_InjectionOCder#(putiO#)ncomments)-(FOr_Yes- -------------------------------------------------------------- ---- 15 -Altw~~)s_wlthin114_miiea~e~-ofreyiawidentif'red(FotservicewePonly)------ ---------Yes- -_-----.------------------------------------------------- -- -- -- ~; 16 Pte-producedinjectoe duration ofprs-pro~uctloolessthan3months_(For_servicewallonJy)---NA- ---------------------------------------------------------- ---- 17 Nonconven, gas conforms )o AS31,05.030~,1 •A),(1.2.A•D) - - - - - - - - - ~- - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - Engineering 18 Conductorst[in9p~--- - --- ---- -- - - -- -Yes --- - -- -- --- - -- - -- -- -- ---- - ---- 19 Sutface_casin4prota4tsaltknownUSRWs--------------------- ---------NA-- ----_NoaquifQrs,_A1O18A,conrdusi9n3•----------------------- ------------------------ 20 CMT_voi adequate- to oirculateon conductor 8 surf-CSg - - - - - - - - -Yes . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_voladaquate_toile-in longstrin®tosurfesg----------------- ----------~0-- -------------------------- ----- ---- - - - - --- ~ 22 CMT_willcovarallknownpraductivehQrizons--------------------- ---------No-- ------Preferforated6ner Dlanned.--------------------------------------------------- 23 Casing designs adequatef9rC,T S&_petmafrost- ----- -- --- - --- --Yes --- - - -- -- -- ----- - -- --- - ----- ----- -- 24 Adequate tankage_o1 reserve pit _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ Yes _ - _ _ - -Rig equipped with steel pits. No,reserve pit plannacl.-Waste to-authorized annuji o[disposal wall(g)._ _ _ _ _ _ _ _ 25 Ifa_re~drilt,bas_atl)•403forabandontnentheenapRroved------------- ---------NA-- --------------------------------------------------- - -- --- --- 26 Adequate.wellbore separaGon_ptoposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Proximity analysis performed, Traveling cylinder path ca~ulated. Gyros likely in surface hole, - - _ _ _ _ _ _ _ - _ _ 27 If d)vertertequired,does)t_maetregulati9ns_____________________ _________ NA_ ______Diverterwaiverrequested,NoissuesinpriorTOwells.________.___________--__________ Appr Date 128 Drilling fluid program schematic-& equip list_adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Maximum expected formation pressure 8,7-EMW._ Planned_MVY uR to-10,5-Ppg•- - - . - - - - - - - - - - - - - - - - - TE 412312008 29 BOPEs,_dotheymeetregulation--------- -- - -- ----Yes --- -- - - - -- - ------ --- - - - -- --- 30 BOP)=-press rating apDroptiate; test to-(put psig in_con~menis)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ . _ _ _ _ _ MASP calculated at 2589psi, 3500_pBi-BOP testpianned. _ _ _ _ _ - _ _ _ _ _ _ _ . _ _ - - _ _ - - _ _ . _ _ _ _ _ _ _ _ !• 131 Choke_roanifoid compliesNrlAPtRP-53 ~May84)- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ 32 Work will ocour whhoutoperation shutdown- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is Rresenceof N2S gas probable- - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ N2$ is notreported at Alpine, R~_equiPped with sensors and alarms.- - - - - - - - - - - - - - - - - - - - - _ - - - 34 MechankatcsmdflionofvJallswithinAORvarifed(focservicewellonly)----- -------- NA- ---------------------------------------------------------- ---- Geology 35 Petmitcan be issued wlo hYdrogensuffide measures - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . . _ _ _ _ None anticipated but H2S measures will_be taken_ _ _ _ _ _ _ _ __ _ _ _ _ _ - - _ _ _ _ _ - _ _ _ _ _ 36 Data_ptasented an potential overpressure zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - _ _ _ _ Expected resenroirpressure is 8,7-pP9 EMN(; wili:be drilled with 8.$ -10.5 ppgmud.because of- - _ _ _ _ _ _ _ - _ _ Appr Date ;37 Seismic analysis of shallow gas_zones__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ - _ - - _ potential for )ncreased-pressure from offset injectors CD2~54 and OD2.59. - _ - _ _ - _ _ _ _ _ _ . _ _ _ _ _ _ _ - - _ _ SFD 4/22!2008 138 -Seabedcondkionsunrey_(rfoff-shore)------------------------- --------- NA_ ____-____----.- 39 Conlactnamelphoneforweek~_progress[epode(exploratoryon~t]----.-- ---------Yes- ------Chip Ahrord,_807~265.6120---------------------------------------------------- Geologic Engineering P Date Date: ' Daie Commissioner: sio Co C issione : ~~~ ~~ ~ Z~~ ~L ~ ~ 4~ • ~~ Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. cd2-75.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jun 18 15:11:51 2008 Reel Header Service name .............LISTPE Date . ...................08/06/18 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/06/18 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION Library Library. CD2-75 501032057300 ConocoPhillips Sperry Sun 18-JUN-08 MWD RUN 2 MWD RUN 4 Mw-000577245 Mw-000577245 J.BOBBIT E. QUAM D.BURLEY D. MICKEY SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: FSL: 3064 FEL: 2043 FWL: 0 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRIC K FLOOR: 52.30 GROUND LEVEL: 15.60 WELL CASING RECORD Page 1 scientific Technical services scientific Technical services Alaska, Inc. ~0~~6~~/ ~Co~o~~ t 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd2-75.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 13.750 3353.0 6.750 7.625 15702.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDSRr), AT-BIT INCLINATION (ABI), AT-BIT GAMMA. (ABG), GEO-PILOT ROTARY STEERABLE SYSTEM (GP)AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 3 SENSORS DID NOT EXIT CASING - NO DATA OTHER THAN SROP PRESENTED. SROP DATA MERGED ONTO START OF MWD RUN 4. 6. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AT-BIT INCLINATION (ABI), GEO-PILOT ROTARY STEERABLE SYSTEM (GP), FORMATION PRESSURE WHILE DRILLING (GEOTAP) AND PRESSURE WHILE DRILLING (PWD). 7. AT-BIT GAMMA (ABG) DATA MERGED ONTO INTO SGRC AT THE END OF MWD RUN 2. 8. RESISTIVITY DATA PRESENTED FOR MWD RUN 4 HAS GAPS IN DATA DUE TO A SENSOR MALFUNCTION. 9. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. l0.MWD RUNS 1-4 REPRESENT CD2-75 WITH API # 50-103-20573-00. THIS WELL REACHED A TOTAL DEPTH OF 23539 MD, 7355 TVD. SROP = SMOOTHED RATE SGRC = SMOOTHED GAMMA SEXP = SMOOTHED PHASE SHALLOW SPACING). SESP = SMOOTHED PHASE (SHALLOW SPACING). ~F PENETRATION WHILE DRILLING. RAY COMBINED. SHIFT-DERIVED RESISTIVITY (EXTRA SHIFT-DERIVED RESISTIVITY Page 2 C] cd2-75.tapx SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3326.0 23482.0 RPD 3348.0 23489.0 FET 3348.0 23489.0 RPS 3348.0 23489.0 RPM 3348.0 23489.0 RPx 3348.0 23489.0 ROP 3363.0 23539.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3326.0 15717.0 4 15717.5 23539.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing .....................60 .lIN Page 3 cd2-75.tapx Max fr ames per record ..... .. ......undefin ed Absent value ... ........... .. ......-999 Depth Units. .. . . ..... Datum specifica tion Block sub-type...0 Name serv ice order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Serv ice Unit Min Max Mean Nsam Reading Reading DEPT FT 3326 23539 13432.5 40427 3326 23539 RPD MWD OHMM 0.08 2000 16.5192 39809 3348 23489 RPM MWD OHMM 0.1 1782.65 13.5754 39809 3348 23489 RPS MWD OHMM 0.11 1451.92 12.2209 39809 3348 23489 RPX MWD OHMM 0.48 24.76 7.74039 39809 3348 23489 FET MWD HR 0.22 63.71 0.629368 39809 3348 23489 GR MwD API 41.66 386.67 94.5502 40313 3326 23482 ROP MWD FPH 0.32 584.61 156.811 40353 3363 23539 First Reading For Entire File..........3326 Last Reading For Entire File...........23539 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 Page 4 ~ ~ cd2-75.tapx FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3326.0 15714.5 FET 3348.0 15665.0 RPX 3348.0 15665.0 RPS 3348.0 15665.0 RPM 3348.0 15665.0 RPD 3348.0 15665.0 ROP 3363.0 15717.0 LOG HEADER DATA DATE LOGGED: 16-MAY-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.6 MAXIMUM ANGLE: 83.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718512 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3353.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 42.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.500 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .690 158.0 MUD FILTRATE AT MT: 1.300 69.0 MUD CAKE AT MT: 2.100 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ...........0 Data Specification Block Type.....0 Logging Direction .................DOwn Page 5 ~ ~ cd2-75.tapx Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3326 15717 9521.5 24783 3326 15717 RPD MWD020 OHMM 0.08 2000 6.81042 24635 3348 15665 RPM MWD020 OHMM 0.1 1782.65 6.58356 24635 3348 15665 RPS MWD020 OHMM 0.11 1451.92 6.15251 24635 3348 15665 RPX MWD020 OHMM 0.48 24.76 5.68669 24635 3348 15665 FET MWD020 HR 0.22 63.71 0.586943 24635 3348 15665 GR MWD020 API 48.8 386.67 117.04 24778 3326 15714.5 ROP MWD020 FPH 0.32 486.79 185.016 24709 3363 15717 First Reading For Entire File..........3326 Last Reading For Entire File...........15717 File Trailer service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. Page 6 a cd2-75.tapx BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 15715.0 23482.0 ROP 15717.5 23539.0 RPX 15735.0 23489.0 RPD 15735.0 23489.0 RPM 15735.0 23489.0 FET 15735.0 23489.0 RPS 15735.0 23489.0 LOG HEADER DATA DATE LOGGED: 27-MAY-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.9 MAXIMUM ANGLE: 92.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 ELECTROMAG. RESIS. 4 228501 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 15702.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 46.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 94000 FLUID LOSS (C3): 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .080 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .033 179.0 MUD FILTRATE AT MT: .120 70.0 MUD CAKE AT MT: .100 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Page 7 • • cd2-75.tapx Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MwD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15715 23539 19627 15649 15715 23539 RPD MWD040 OHMM 8.91 57.72 32.2814 15174 15735 23489 RPM MWD040 OHMM 7.4 42 24.9267 15174 15735 23489 RPS MWD040 OHMM 7.03 39.26 22.0729 15174 15735 23489 RPX MWD040 OHMM 5.66 22.27 11.0746 15174 15735 23489 FET MWD040 HR 0.31 29.37 0.698328 15174 15735 23489 GR MWD040 API 41.66 116.06 58.6799 15535 15715 23482 ROP MWD040 FPH 2.85 584.61 112.264 15644 15717.5 23539 First Reading For Entire File..........15715 Last Reading For Entire File...........23539 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EoF Tape Trailer Service name .............LISTPE Date . ...................08/06/18 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Reel Trailer Page 8 Service name .............LISTPE gate . ...................08/06/18 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File cd2-75.tapx writing Library. 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