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Home My WebLink About210-008CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-124 (PTD# 210-008) Date:Wednesday, May 29, 2024 1:33:52 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, May 29, 2024 1:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Dodson, Kate <Kate.Dodson@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD3-124 (PTD# 210-008) Chris, The 30-day monitor on water will end on June 2nd. The well looks stable. CPAI will conduct a 30-day monitor on MI. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Kate From: WNS Integrity Sent: Wednesday, January 31, 2024 10:37 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Dodson, Kate <Kate.Dodson@conocophillips.com> Subject: CRU CD3-124 (PTD# 210-008) Chris, CRU CD3-124 (PTD# 210-008) was reported by operations for high IA pressure. The well has been shut it and initial diagnostics are ongoing. After initial diagnostics, the well will be put on a 30-day monitor on water injection. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-124 (PTD# 210-008) Date:Wednesday, January 31, 2024 10:42:02 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, January 31, 2024 10:37 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Dodson, Kate <Kate.Dodson@conocophillips.com> Subject: CRU CD3-124 (PTD# 210-008) Chris, CRU CD3-124 (PTD# 210-008) was reported by operations for high IA pressure. The well has been shut it and initial diagnostics are ongoing. After initial diagnostics, the well will be put on a 30-day monitor on water injection. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, April 13, 2020 8:01 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU Injector CD3 -124 (PTD 210-008, A10 30.011) Gas Injection Diagnostics Attachments: CD3-124.pdf; CD3 -124 90 day TIO Plot 4-13-20.pdf Chris, CRU injector CD3 -124 was recently granted administrative approval for water injection only due to know TxIA communication on gas injection (AIO 30.011). But due to the benefit of gas injection into the pattern, ConocoPhillips would like to continue with gas injection diagnostics. We plan to swap out a dummy valve that was the leak path for TxIA on gas injection back in 2015 then place the well on a 60 day monitor on gas injection. Attached are the well schematic and a 90 TIO plot. Please let me know if you have any questions or disagree with the plan forward. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, March 24, 2020 5:03 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: Alpine WAG Injector CD3 -124 (PTD 210-008) Report of Unexplained IA Pressure Increase - End of Monitor Attachments: CD3 -124 90 -Day TIO Chart 3.24.20.pdf, CD3-124.pdf, CD3 -124 Diagnostic MIT.xlsx Good Afternoon Chris, As per the email below, CD3 -124 (PTD 210-008) was online in gas -injection service from 2/5/20 through 2/21/20 to perform diagnostics to understand repair options for the well. Unfortunately, this time period had numerous weather days that continually delayed the diagnostics, so the well was converted to water injection on 2/23/20 and is presently injecting. During the 30 -day water -injection monitor period, no communication was evident, thus CPAI intends to progress administrative approval for water -only injection with known tubing by inner annulus communication in gas injection service. The well passed an MIT -IA to 3000 psi and tubing/inner casing pack -off tests on 1/31/20. CPAI intends for the well to remain online in water injection service while we prepare the waiver request packet, which is anticipated to be submitted by the end of this week. Additionally, CPAI intends to continue to progress diagnostics to understand the nature of the leak to gas and commence a repair if possible. Please let me know if you have any questions or disagree with the plan forward. Attached is a schematic, the MIT results, and a 90 -day TIO plot of the monitor period for your review. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Thursday, January 23, 2020 9:18 AM To: 'ch ris.waIlace @alaska.gov' <chris.waIlace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: Alpine WAG Injector CD3 -124 (PTD 210-008) Report of unexplained IA pressure increase Good Morning Chris, I wanted to follow up on our previous correspondence and amend the plan forward for diagnostics on CD3 -124 (PTD 210-008). We intend to continue operating the well in gas injection service to understand the nature of the IA pressure increase. It would be beneficial to complete the previously suggested diagnostics (MIT -IA and pack -off tests) while in gas injection service to understand potential repair options in hopes to preserve the ability to continue future gas -injection service. 2015 diagnostics indicated the lower dummy valve as a previous source of tubing by IA communication on gas injection and we intend to investigate that area as needed. The amended path forward is to allow the well to remain in gas injection service for diagnostics and repair, then commence a 30 -day monitor on gas injection. If the source of the IA pressure increase is unable to be determined or repaired, CPA[ intends to convert the well to water injection only for a 30 -day monitor period and will perform additional diagnostics as needed. Please let me know if you have any questions or disagree with the plan forward. Sincerely, SGi,rw Ca rUA& L"T" (eirGl rv) / ,Ste pl'I.AnV & Pi di, Well Integrity & Compliance Specialist, WNS & C1PF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Tuesday, January 21, 2020 4:09 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: Alpine WAG Injector CD3 -124 (PTD 210-008) Report of unexplained IA pressure increase Chris, Alpine WAG injector CD3 -124 (PTD 210-008) has recently exhibited an unexplained increase in IA pressure. Operations bled the IA but the pressure resumed increasing post -bleed. The build-up rate is relatively slow in nature. CPAI intends to WAG the well to water injection then conduct IA diagnostics which will consist of an MITIA, packoff tests, and an IA - drawdown test. Attached are the 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, January 21, 2020 4:09 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: Alpine WAG Injector CD3 -124 (PTD 210-008) Report of unexplained IA pressure increase Attachments: CD3 -124 Wellbore Schematic.pdf, CD3 -124 90 day TIO Trend 1-21-20.pdf Chris, Alpine WAG injector CD3 -124 (PTD 210-008) has recently exhibited an unexplained increase in IA pressure. Operations bled the IA but the pressure resumed increasing post -bleed. The build-up rate is relatively slow in nature. CPAI intends to WAG the well to water injection then conduct IA diagnostics which will consist of an MITIA, packoff tests, and an IA - drawdown test. Attached are the 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg /� P.I.Supervisor `•L]el Z7 i� SUBJECT: Mechanical Integrity Tests LL CONOCOPHILLIPS ALASKA,INC. CD3-I 24 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-124 Petroleum Inspector Src: Inspector Reviewed B�yy::�j- P.I.Supry COP-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-124 API Well Number 50-103-20612-00-00 Inspector Name: Lou Laubenstein Permit Number: 210-008-0 Inspection Date: 2/11/2018 Insp Num: mitLOL180212125206 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j CD3-124 Type Inj W •TVD 6580 - Tubsng l 2479 2479 2479 2479 BBL Pumped: 2 BBL 1060 1900 1880 1880 PTD 2100080 !Type Test SPT Test psi 1645 ! IA L Returned: 1.9 OA 345 430 - 429 - 426 1 Interval - — — _-- __-_ 4YRTST P/F P Notes: SCANNED / 1 ; ' ... ary 20,Tuesday, Febru 2018 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday,April 11, 2015 10:27 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: Alpine WAG Injector CD3-124 (PTD 210-008) Update 4-11-15 Attachments: image001.png; CD3-124 90 Day TIO plot.JPG Chris, Alpine WAG injector CD3-124 (PTD 210-008) is nearing the end of the 30 day MI injection period. As previously reported,the initial diagnostics passed and the IA has not displayed signs of re-pressurization during the 30 day MI injection monitor period. At this point in time CPAI will return the well to"Normal" injection status. Please let us know if you have any questions or disagree with this plan. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 ,wELLS TEAIVI , SCAAPR 2 3 201 Fro • NSK Problem Well Supv Sent: Tu- •ay, March 10, 2015 10:29 AM To: Wallace, • 's D (DOA) Cc: NSK Problem - Supv Subject: RE: Alpine WA Vector CD3-124 (PTD 210-008) Update 3-10-15 Chris, Alpine WAG injector CD3-124 (PTD 210-008) diag •stics have been completed. The lower dummy valve suspected to be the source of communication was replaced after the w- .ore was circulated out with clean fluids. A passing MIT-IA was performed after replacing the dummy valve (see attached for • CPAI intends to bring the well on MI gas for a 30 day monitor period to verify that the communication source has been e '••inated. If the well continues to demonstrate IA pressure increase while on MI gas the well will be WAG'd to water for a : •ay monitor period. At the conclusion of the monitor period(s)CPAI will provide a follow up email and submit any required •; serwork. Please let us know if you disagree or have any questions with this plan. Thank you, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7126 1 .. W ij U1 X UI % za' CC N w w a _ U N W Cr (Y v- ia. ,-- or u- e" o O N N & t,- o - a v o a v x U W m N . ', ,- a I, o- en u, Is, W O `- ! i_ 2 N N CM V V 1 .- J J C U ri U U U O o O O O dip O in li, LI O a u, u1 a a ri G • 3 (4 ` u) N C r 4 C 4 175 ✓ u u, a E E o u, u, U- N le LI- 0 3 Z G w u Q - c o a LY, Qa a N C O ✓ eV cz, N 1 0 V.'''.." .Cr.--* . III I n E �cv./ t � 1 1 { 1 { I1 ay O OQ ^ Se } $ Q Z O 16 O O O O O O O O O + " r U, O U, O u, O U, O VU , Od 18 3.)• 1/1 Q ea el el N N — !- 01W >'4 isd SScn0W Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, March 10, 2015 10:29 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv Subject: RE: Alpine WAG Injector CD3-124 (PTD 210-008) Update 3-10-15 Attachments: image001.png; MIT CRU CD3-124 diagnostic 03-09-15.xls Chris, Alpine WAG injector CD3-124 (PTD 210-008) diagnostics have been completed. The lower dummy valve suspected to be the source of communication was replaced after the well bore was circulated out with clean fluids. A passing MIT-IA was performed after replacing the dummy valve (see attached form). CPAI intends to bring the well on MI gas for a 30 day monitor period to verify that the communication source has been eliminated. If the well continues to demonstrate IA pressure increase while on MI gas the well will be WAG'd to water for a 30 day monitor period. At the conclusion of the monitor period(s) CPAI will provide a follow up email and submit any required paperwork. Please let us know if you disagree or have any questions with this plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 SCANNED MAR 1 0 2015 WELLS TEAM ConocoPhillips From: NSK Problem Well Supv Sent: Monday, February 16, 2015 4:41 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: FW: Alpine WAG Injector CD3-124 (PTD 210-008) Report of unexplained IA pressure increase Chris- Alpine WAG injector CD3-124(PTD#210-008) was recently reported for an unexplained increase in the IA pressure. The initial diagnostics were completed which consisted of a passing MIT-IA and passing T and IC pack off tests. However,the IA DDT showed slow but steady build up. Because the well was most recently injecting MI gas and the logistics of getting a pump truck and a substantial amount of fluids to CD3, it is CPAI's intentions to bring the well on water injection for a period of no more than 7 days to displace the well bore with fluids to create a safer work environment for the diagnostic well work. Depending on the results of the diagnostics the proper paperwork for repair or continued injection will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a current 90 day TIO and well bore schematic. 1 Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 414WELLS TEAM From: NSK Problem Well Supv Sent: Monday, December 08, 2014 10:49 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine WAG Injector CD3-124 (PTD 210-008) Report of unexplained IA pressure increase Chris, Alpine WAG Injector CD3-124(PTD 210-008) has recently exhibited an unexplained increase in IA pressure. Operations bled the IA, but the pressure resumed increasing post bleed. At this point in time the IA pressure build up rate is relatively slow in nature. CPAI intends to leave the well on MI injection while mobilizing DHD to Alpine and conduct initial diagnostics to include an MIT-IA, pack off tests and an IA draw down test. Depending upon the results of the diagnostics CPAI intends to leave the well on MI injection for a 30 day monitor period, WAG the well to water injection for a 30 day monitor period,or shut in and freeze protect the well. At the conclusion of the diagnostics and monitor period CPAI will provide a follow up email with the plan forward and submit any required paperwork. Attached are the 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM coax:41 iris 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to• jim reaa aaalaska.gov; AOGCC.Insoectorsaalaska.gov; phoebe.brooks@alaska.gov chris.wallaceaalaska.00v OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT 1 PAD: Alpine/CRU/CD3 DATE: 03/09/15 OPERATOR REP: AHERN AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-124 Type Inj. N , TVD _ 6,580' Tubing 500 720 717 712 Interval 0 P.T.D. 2100080 Type test P Test psi 1645 Casing 241 3,023 3,006 2,999 P/F P Notes: Diagnostic MIT-IA OA 26 37 36 36 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P T.D. Type test Test psi Casing P/F Notes: OA, TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Infecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT CRU CD3-124 diagnostic 03-09-15 xis Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, February 16, 2015 4:41 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: FW: Alpine WAG Injector CD3-124 (PTD 210-008) Report of unexplained IA pressure increase Attachments: image001.png; CD3-124 wellbore.pdf; CD3-124 90 Day TIO.JPG Chris- Alpine WAG injector CD3-124 (PTD#210-008) was recently reported for an unexplained increase in the IA pressure. The initial diagnostics were completed which consisted of a passing MIT-IA and passing T and IC pack off tests. However, the IA DDT showed slow but steady build up. Because the well was most recently injecting MI gas and the logistics of getting a pump truck and a substantial amount of fluids to CD3, it is CPAI's intentions to bring the well on water injection for a period of no more than 7 days to displace the well bore with fluids to create a safer work environment for the diagnostic well work. Depending on the results of the diagnostics the proper paperwork for repair or continued injection will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a current 90 day TIO and well bore schematic. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 ilfWELLS TEAM SEWED MAR 0 4 2015 ConocoP} ips From: NSK Problem Well Supv Sent: Monday, December 08, 2014 10:49 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpige WAG Injector CD3-124 (PTD 210-008) Report of unexplained IA pressure increase Chris, �.` Alpine WAG Injector CD3-124'*TD 210-008) has recently exhibited an unexplained increase in IA pressure. Operations bled the IA, but the pressure resumed increasing post bleed. At this point in time the IA pressure build up rate is relatively slow in nature. CPAI intends leave the well on MI injection while mobilizing DHD to Alpine and conduct initial diagnostics to include an MIT-IA, packQff tests and an IA draw down test. Depending upon the results of the diagnostics CPAI intends to leave the well on MI injection for a 30 day monitor period, WAG the well to water injection for a 30 day monitor period,or shut in and freeze protect the well. At the conclusion of the diagnostics and monitor period CPAI will provide a follow u ail with the plan forward and submit any required paperwork. Attached are the 90 day TIO trend and wellbore schematic. 1 U VJ N 2 2 Cr: d' W W W N U yH 0_/ rn " u, Ei O H W DI CC O O 0 v o cn �� V x a W m y rl el, CO N o N N I- V) V -f W .- 0 0 t N N E-4 I- 1- V N fV O V n „ 1 N N N J ri r) r, fEJ a LI o S U U U 0 0 0 0 0 o - w o 0 0 0 N - to 22:2 O N O V) l 1 t II t 1 1 1 .i - 41 1 --- 1 LL V) V'i i Li ni V, V_ LL c c d m o C 15 us u, 637 r"`" N an C 0 4 a, Ill 4.5 5 - d u t] v V {n p o N O cO 2 Z e- N p N V ,,- N a $ SERB =o 0. .- _ 3 q m 2 SGi I ( I I I Et 1 1 1 1 1 d 0 R n o o a o 0 o O o2. $ 1 $ v § $ z Z 0m x 31 N b 1.6 M M N N u O W Od)a b/al Z 05 >c I S d S. N 0 W WNS CD3-124 ConocoPhiIIips "•im.,WWell Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Well Status Incl I") MD(MB) Act Btm(ftKB) i,yrKM1vII,Pi 501032061200 FIORD NECHELIK INJ 93.38 20,340.98 23,981.0 Comment MS(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date • Well Confp.HORIZONTAL-CD3-124,11/29/2012 10.10:50 AM SSSV:TRDP Last WO: 42.49 3/9/2010 Snhematlo-ACNeI Annotation Depth((K8) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:DRILL DATES/OPEN HOLE osborl 11/29/2012 HANGER,31 Casing Strings Cuing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded 24"Insulated - -- Cooing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD).-String Wt..String...String Top Thrd SURFACE 103/4 9.950 36.0 3,540.2 2,468.8 45.50 L80 BTCM Cooing Description String 0... String ID...'Top(MB) Set Depth(f...Sot Depth(TVD)...String Wt..String...String Top Thrd 1 INTERMEDIATE 75/8 6.875 33.8 17,888.3 7,070.7 29.70 L-80 BTC-m Casing Description String 0... String ID...Top(P1KB) Set Depth(f...Set Depth(TVD)...String Wt..String.•.String Top Thrd OPEN HOLE 6 3/4 21,000.0 23,981.0 7,003.1 CONDUCTOR Casing Description String 0... String ID...Top(P1KB) Set Depth ff...Set Depth(TVD)...String Wt...String...String Top Thrd 24"" LINER 41/2 3.958 17,424.8 21,000.0 7,063.4 12.60 L-80 SLHT Insulated, 37-114N.:,--- --5,'• Details IP ,•,-4 ` • Top Depth ' (TVD) Top incl Nomi... 11 Top(NCB) (MKS) I") Item Description Comment ID(in) 17,424.8 6,999.5 80.71-SLEEVE "HR"Setting Sleeve w/10.13'Seal Bore Receptacle 5.750 = 17,437.5 7,001.6' 80.65 NIPPLE "RS"Packoff Seal Nipple 4.850 - 17,440.0 7,002.0 80.64 HANGER Baker Flexlock"DG"5 1/2"Liner Hanger(Shear Pressure 2,000 Psi) 4.900 SAFETY VLV .1=1.:' 2200111 Tubing Strings Tubing DescriptionString 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING I 31/2 I 2.992 I 30.7 I 15,996.3 I 6,647.9 9.20 I L-80 I EUE I Completion Details Top Depth (TVD) Top Incl Komi... 1 Top(kKB) (ftKB) (0) Item Description Comment ID(In) 30.7 30.7 -0.08 HANGER FMC Tubing Hanger 4.500 SURFACE 35-2 540 128.8- 128.8 1.37 XO-Reducing Crossover-41/2"IBTM Box to 31/2"EUE Pin 2.922 2,200.2 1,966.8 54.51 SAFETY VLV CAMCO-TRMAXX-5E SSSV w/Control Line to Surface;2.813"X-Profile 2.812 SAS LIFT, ---. 15,787.4 6,579.6 70.53 PACKER Baker 312"by 7 5/8"Premier Packer 2.870 8.302 15,835.4 6,595.5 70.57 NIPPLE HES"XN"Nipple Placed @ 71°,w/2.75"MinimumID 2.750 "WLEG 4.63"OD 3.00"ID 3.000 I Perforations&Slots Shot Top(TVD)1 Bbn(TVD) Dene Top(ftK8)Bbn(kKB) (ftKB) (kKB) Zoo Date 61,-61,- Type Comment 17,892.4 18,732.8 7,071.5 7,082.3 3/7/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/P; - no slots 3'from box/pin 1 18,971.7 20,157.9 7,076.5. 7,039.6 -3/72010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; GAS LIFT, 15,995.8 6,647.8 71.48 WLEG 3 1/2no Slots 3'from box/pin 1 12,856 I 20,599.5 20,993.6 7,044.8 7,063.5 3/7201032.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin Notes:General&Safety End Date Annotation 3/21/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0/72 GAS LIFT, 5,807 PACKER, 15,787 NIPPLE,15,835 A , WLEG,15,908 H , NTERMEDIATE, Mandrel Details 34-17,888 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftK8) (ftK8) r) Molts Model (in) Sen, Type Type (in) (psi) Run Date Corn... _=I I - 1 6,302.2 3,399.2 70.64 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2011 SLOTS, • • 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 L 0- Q 0 Z Well History File Identifier Organizing (done) Two -sided I, I ❑ Rescan Needed II I 11111 RE CAN DIGITAL DATA OVERSIZED (Scannable) V Color Items: ❑ Dis ettes, No. ❑ Maps: Greyscale Items: Other, No/Type: a NO. 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 3 / !s! i Project Proofing I 111111101111 BY: Maria Date: 1/3// /s, a f Scanning Preparation 5 x 30 = /5 + = TOTAL PAGES 1 5' 5' (Count does not include cover sheet) BY: Maria Date: 1/LST-97, /s/ IV Production Scanning I 11111 Stage 1 Page Count from Scanned File: ) � (Count does include cover sheet) Page Count Matches Number in Sca ning Preparation: I YES NO BY: Date:' f is/ Al p Stage 1 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. II 111111111 1111 ReScanned 111111111111111111 BY: Maria Date: !s/ Comments about this file: Quality Checked III IIIIII III IIIIIII 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10/19/2011 Permit to Drill 2100080 Well Name /No. COLVILLE RIV FIORD CD3 -124 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20612 -00 -00 MD 23981 TVD 7003 Completion Date 3/9/2010 Completion Status WAGIN Current Status WAGIN I-- REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint 0 Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ' pt LIS Verification 3513 23981 Open 3/23/2010 LIS Veri, GR, RPS, FET, RPM, RPD, RPX, GR, ROP 4U C Lis 19477'"Induction /Resistivity 3513 23981 Open 3/23/2010 OH LIS GR, RPS, FET, i RPM, RPD, RPX, GR, ROP Plus PDF, EMF, TIFF graphics og Induction /Resistivity 25 Col 114 23981 Open 3/23/2010 MD ROP, DGR, EWR Indiction /Resistivity 25 Col 114 23981 Open 3/23/2010 TVD ROP, DGR, EWR D C Pdf 19505 Cement Evaluation 114 23981 Case CGM, EMF, TIFF and PDF graphics og Cement Evaluation 15 Col 114 23981 Case MD BAT, DGR D C .- Directional Survey 36 23981 Open ! Rpt Directional Survey 36 23981 Open III Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y0 Daily History Received? 0/ N Chips Received? --L-4- Formation Tops � Analysis Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/19/2011 Permit to Drill 2100080 Well Name /No. COLVILLE RIV FIORD CD3 -124 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20612 -00-00 MD 23981 TVD 7003 Completion Date 3/9/2010 Completion Status WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: — Date: • • STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISSI ' "' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other Convert to injector Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Tine Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f - 210 - 0080 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic f Service • 50-103-20612-00..00 7. Property D (Lease Number): 8. Well Name and Number: ADL 025526, 380092, 372105 " CD3 - 124 9. Field /Pool(s): ,. Colville River Field / Fiord Oil Pool 10. Present Well Condition Summary: Total Depth measured 23891 feet Plugs (measured) None true vertical 7003 feet Junk (measured) None Effective Depth measured 23891 feet Packer (measured) 15787 true vertical 7003 feet (true vertucal) 6580 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 114 114 Surface 3506' 10.75" 3540 2469 Intermediate 17854' 7.625" 17888 7073 Liner 3575' 4.5" 21000 7063 RPCF 1VED Perforation depth: Measured depth: 17892'- 18733', 18972'- 20158', 20599'- 20994' True Vertical Depth: 7072' - 7082', 7079'- 7040', 7045-7064' 1U L x L - 1 ' 1� + & o . C mf111SS10il Tubing (size, grade, MD, and TVD) 3.5, L -80, 15996 MD, 6648 TVD Niaat O o ll Packers & SSSV (type, MD, and TVD) Baker Premier pkr 5787' M�, 6580' TVD Camco TRMAXX - 5E S 200' MD, 1967' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 2374 3453 85 -- 323 Subsequent to operation 6644 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service. 1 Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r r Daily Report of Well Operations XXX GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG r 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: 311 -123 • Contact Jack Walker @ 265 -6268 Printed Name Jack Walker Title Principal Production Engineer Signature , 265 -6268 Date ` 12— i'l ! 26 // RE, L 5(A-- 7 / 3 // Form 10 -404 Revised 10/2010 lu� '� Submit Original Only CD3 -124 Well Work Summary DATE SUMMARY 5/1/11 GAUGED TBG TO 2.79" TO 15,835' Ilk. PERFORMED SBHPS @ 15,800' RKE.MP =157" PSI =1728) IN PROGRESS. 5/2/11 B &F TBG TO 15,835' RKB. SET CAT SV @ 15,835' RKB. ATTEMPTED TO PULL OV & GLV's. IN PROGRESS. 5/3/11 PULLED OV @ 15,697' RKB. PULLED GLV AND SET DV @ 12,856' RKB. PULLED GLV @ 6302' RKB. LOST / RECOVERED TOOLSTRING. IN PROGRESS. 5/4/11 RECOVERED WIRE (APROX. 18 ") SET DV @ 6302' RKB. CIRC. 600 BBLS INHIBITED SEAWATER AND 70 BBLS DIESEL TBG x IA THEN U -TUBE. IN PROGRESS. 5/5/11 SET 1" DV @ 15,697' RKB. MIT- IA;PASSED. MIT-TBG: PASSED. PULL SV @ 15,835' RKB. COMPLETE. 5/19/11 GAUGED TBG TO 2.78" TO 15835' RKB. MEASURED BHP @ 15800' RKB: 1921 PSI / 152 F. COMPLETE. 5/20/11 PLACED ON INJECTION III N. WNS CD3 -124 C�Ph ° a „ ` Well Attributes Max Angle & MD TD fU aShf3 Inc. ' " �. Wellbore APIIUWI Feld Name Well Status Inc/ ( °) IMD (ftKB) Act Btm (ftK6) (,aaamAxlhln 501032061200 1 FIORDNECHELIK INJ L93 -38 1 20,340 98 23,981.0 Comment H2S (ppm) (Date Annotation End Data I KB -Grtl (it) Rig Release Date Well Config; HORIZONTAL CDC 1 4, 6/15/2011 4 27 05 PM SS TRDP Last WO. 42.49 3/9/2010 S nema-c Actual Annotation Depth (ftKB) End Date Annotation Last Mod .... End Date Last Tag_ Rev Reason: GLV C/O mnam 6/15/2011 ■ Casing Strings HANGER, 3, -- .ti _. -.. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR24" 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Insulated Casing Description String 0... String ID ... Top (111(8) Set Depth (1... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 36.0 3,540.2 2468.8 45.50 L80 BTCM , Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD)... String Wt... String .. String Top Thrd _ _ - INTERMEDIATE 7 5/8 6.875 33.8 17,888.3 7070.7 29.70 L BTC - m ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (ND) ... String Wt... String .. String Top Thrd LINER 4 1/2 1958 17,424 8 21,000 0 7,063.4 12.60 L-80 SLHT __ CONTOR ^ - a ` Liner Details_ 2a Inw - - Top Depth 37 -114 Nomi... e '<; To• ) ( ftKB) (ND) To ' Item Description C omment 10(in) 17,437.5 6999.5 999.5 80.75 NIPPLE SLEEVE "HR" Setting Sleeve w/ 10.13' Seal Bore Receptacle 5.750 "RS" Packoff Seal Nipple 4.850 17,440.0 7,002.0 80.64 HANGER Baker Flexlock "DG" S 12" Liner Hanger (Shear Pressure 2,000 Psi) 4.900 I , 17,449.8 7,003.6 80 -59 XO - Reducing XO - 5 1/2" Hydril 521 Box to 4 1/2" SLHT Pin 3.930 SAFETY VLV, Tubing Strings Tubing Description / String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd , TUBING 31/2 2.992 30.7 15,9963 6,647.9 9.20 L-80 I EUE „GQmpletion Details Top Depth i (ND) Top Inc! Nomi... Top (flK7 ( 3 ( 0 XO - Red crig FMC Tu er n9 41 /2 BTM Box to 3 G 12 " EUE Pin 1 2.92 , 2 . SURFAC 36 -3.540 !'; 2,200.2 1,966.8 54.51 SAFETY VLV CAMCO - TRMAXX -5E SSSV w/ Control Line to Surface; 2.813" X-Profile 2.812 15,787.4 6,579.6 70.53 PACKER Baker 3 1/2" by 7 5/8" Premier Packer 2.870 GASUPr, . 15,835.4 6,595.5 70.57 NIPPLE HES XN Nipple Placed X71 °,w /275 "Minimum ID 2.750 6 '302 15,995.8 6,647.8 71.48 WLEG 3 1/2" WLEG 4.63" OD 3.00" ID 3.000 I Perforations & Slots . Shot Top (TVD) Btm (ND) Dens Top (1tKB) Btm (ftKB) (RKB) (ftXB) Zone Date ( °• Type _ Comment 17,892 18,733 7,071.5 7,082.3 3/7/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin 18,972 20,158 7,078.5 7,039.6 3/7/2010 32.0 SLOTS Slots 1/8x2.25 °, 8 slots/row, 4 rows/ft; no slots 3' from box/pin 1zsss GAS ,856 _ - ----- a: -: - 20,599 20,994 7,044.8 7,063.5 ' 3/72010 32.0 SLOTS Sias 1/8x2.25 ", 8 slots row, 4 rows/ft; no slots 3' from box/pin Notes: General & Safety End Date Annotation I 3/21/2010 NOTE: VIEW SCHt - MA I IC w /Alaska Schemaxc9 0 GAS LIFT, 15,697 PACKER, 15.787 4 NIPPLE, 15,835- - - ---' WLEG, 15,996 1! i Mandrel Details Top Depth Top Port NTERMEDIATE, (TVD) Inc/ OD Valve Latch Si2e TRO Run 34-17,888 Stn Top(ftXB) (RKB) ( "1 Maio Mo6e1 _ (in) Sery Type tYPe (in) (Pa0 Run Date Cam... -.-..- -- 1 6,302.2 3,399.2 70.64 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/42011 MOTs 1 1 --^ 2 12,856.3 5,595.9 70.41 Camco KBMG 1 GAS LIFT OMY BK 0.000 0.0 5/3/2011 wtant -Swan 17,892 -18,733 e ' ms - , . i t .., ",1m 3 15,697.3 6,549.5 70.46 Camco KBMG 1 GAS LIFT DMY BK 0.000 I 0.0 5/52011 SLOTS. _ ". 18,972- 20,158 SLOTS, � I _ 20,599- 20,994 '3 1 1 21 1 1 __ LINER, I 17,425- 21,000 • TD, 23,981 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: 210 -0080 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -124 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20612 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final IS 310 -088 4/8/2010 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 SP any necessary water added Previous 382* 382 totals (bbls): 2010/2nd 0 0 0 0 0 2010/3rd 0 0 0 0 0 2010 / 4th 0 0 0 0 0 2011 / 1st 31514 100 0 31614 24 3/8/2011 3/31/2011 CD3 -125, CD3 -198, CD3 -199 2011 / 2nd 0 0 0 0 0 la Total Ending Report is due on the 20th Volume 31514 100 382 31996 24 (bbls): of the month following the final month of the quarter. Ex: 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): *freeze protect volumes only I hereby certify that the foregoing is true an correct to the best of my knowledge. Signature: IJrf/k- Date: 16 (14 it I Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 corm 1U-41.3 Key. L /ZUU4 INb 1 KUtw I IONb ON KtVtKbt blUt buomlt in uupucate • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, June 27, 2011 Jim Regg P.I. Supervisor Reei 711Ct fl, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3 -124 FROM: Jeff Jones COLVILLE RIV FIORD CD3 -124 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv�jI � — NON - CONFIDENTIAL Comm Well Name: COLVILLE RIV FIORD CD3 - 124 API Well Number: 50 103 - 20612 - 00 - 00 Inspector Name: JeffJones Insp Num: mitJJ110606072502 Permit Number: 210 - 008 - Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3 -124 ` Type mi. w l TVD 6580 ' IA 986 r 2018 2028 2033 . 2037 - 2039 - P.T.D moon ' TypeTest SPT Test psi 1645 - OA 441 571 580 587 590 592 Interval ,- p/F P - Tubing 1578 1591 1607 1533 1535 1535 Notes: 0.5 BBLS diesel pumped. 1 well house inspected; no exceptions noted. I I Monday, June 27, 2011 Page 1 of 1 I0 • • STATE DIF ALASEA SEAN PARNELL, GOVERNOR t�T�+�1 ls ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COLTISSIO1s ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jack Walker Principle Production Engineer g ConocoPhillips Alaska, Inc. 0 10-0 P.O. Box 100360 d � Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3 -124 Sundry Number: 311 -123 Dear Mr. Walker: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. Si erel 0 . orman Co mis ..ner DATED this i of April, 2011. Encl. STATE OF ALASKA lip I RECEIVED .. ALAS AND GAS CONSERVATION COMMI APR 13 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Altstal MA A fiit Ceps- NI mission 1. Type of Request: Abandon "-' Plug for Redrill r Perforate New Pool r Repair w ell f Change Appop. om r Suspend J" Flug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Convert from Producer to \t4 i • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (; • Exploratory r �2 ,0 / 6008 D d: 3. Address: 6. API Number: Stratigraphic r Service '"" P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20612 - 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 r No CD3 - 124 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 025526 :380092, 372 /OS Colville River Field / Fiord Oil Pool • 11. /SC q. / •// PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 23891' • 7003' • 23891' 7003' Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 114' 114' Surface 3506' 10.75" 3540' 2469' Intermediate 17854' 7.625" 17888' 7073' Liner 3575' 4.5" 21000' 7063' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 17897 18733', 18972' 20599' 20996' 7073' - 7082', 7078' - 7042', 7045 4.5" / 3.5" L-80 15996' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker packer 15787' MD / 6580' TVD Camco SSSV 2200' MD / 1967' TVD 12. Attachments: Description Summary of Proposal Iv 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch Exploratory Development Service J;i 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/25/2011 011 r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG Fi • Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265 -6268 Printed Name Jack Walker Title: Principal Production Engineer Signature �� ] — Phone: 265 -6268 Date 1 /n 2-cd f( U Commission Use Only Sundry Number: 5( I., 0 3 Conditions of approval: Notify Commission so that a representative may witness (J t Plug Integrity J"` BOP Test r Mechanical Integrity Test i lk Location Clearance r Other: Subsequent Form Required: / d - tiv ty el / APPROVED BY / S Approved News APR 15 ZQ 1 COMMJSSIONER THE COMMISSION Date: Y lit • / , Form 10 -403 Revised 1 /2010 ��1 y II 1 GI n ! A L Y � �,/ Submit in Dupl � y / l ry r CD3 -124 Description Summary of Proposal Convert from Producer to WAG Service 13 -April -2011 1. Load inner annulus with corrosion - inhibited seawater with freeze protect cap. 2. MITIA. 3. Measure static BHP. 4. Convert surface facility tie -in from production to injection. ✓ 5. Put on injec on. ). I4/4ne,sse_I t T - �A- A {- r S 11-4.,10 L � 1 ~ � WNS CD3-124 ConocoPhillips if; w.lI Attributes Max An•l. a MD TD m u s . 0 c81 ,a.o¢445 50032081:80 FARO NEOHELM PROD 23 9810 Camiw.t - _ _ -__. • .. .�..w - ua�xeRSR5:�8iAI¢:1Pa� ss., TRDP i�ll� ®�� 8 . a w M i lRev Rom New VIN, P. 8x5 o.I. GLV C/O I� 8`1201 ONDUCTOR 2J' L 30 fu„ Inalateo EilikiiiiillhaillikalibilliiithilliiiithilhailiffiliiiiiEfil =''v EO nTe I liiiiiiii '�: " mo 7 1 .. iffil ' ]� , lo NEM — . Ili 1 __ LINER . ' . ®Ili 21000-0 — Toe 3_ ®ffilI INEMIIIII 11 ibililifialgoldlagliali 930 '''' : -: Tubing Strings a il'r Mon iu I .%2 �� ( TT -3011 115 17.7 -1fMy 1 . 1 .. r" Z. Completion Details r o n D ' ion. T r■ ...0.4alp. Comm D W.1 80.7 80.7 -0.08 HANGER FMC Tub na Hmge- .500 7:4 a 128.8 1288 1.37X0- RM.nwy Cm44ow8 41 8o• to 31.T EUE Po 2922 2,200.2 19% 54.515AFETV VLV CAMCO- TRIM % -SE SSSV wI Control Loot to SM. 2813 - XAM. 2812 I■ 15.757 e en 6 7053 PACKER 8.1. 31.' 8 7 '18' Pmmo0 P... 2870 .8= l... 18835.4 85053 70.57 NIPPLE HES Nipple AIM $ 71' 275•M"....um 10 2.750 15995.5 6,8478 7148 WI EG 31/: MEG 4. 53 . 0D 30D'4 5000 Perforations & Slots fm. Too lnXBl a. mK91 m ∎OP mu1 1 u,., om. Iiiiilliiiiiiiiiii 111111111111 ° V. { Notes: General a Safety Ene 0wa Maw/. 8n1.010 f NCTE VIEW SCHEMATIC w Arita S.M. 0 I5, e. �.eelela N..ISlSm M. IS 2. a k ,, Mandrel Details �ff�,,I;pp;IytS I7fvc .fm Bi '�6 6CiMMI"VoiilrlliilMM{'liM llliiiiil _ m524 �I ! .74x=1 "...........e 1 Airt Kr. MARI CAT, a2iTEGRITY' REURT • SPUD u . = = . : 02 7 6 '45/ 4 " OPER & YIELD CPAT C es r. +.rti..ssVr• ..ms Lioe M:..SJ+K. ..G a.. -3 3: .4... K ..-- _.. +w..�... - 7 G n "?.. A. S.i . • 3 -`)' 70/0 +M-L NUMBER C .. ..` 1 Zy .. .LL DATA 'a:1) a 2391'I .? .. 700.3 T D ; 'r-IT'D . 23/81 ?a) 7003 INIM Casing. 7 a w Slane: 779elale 7073 T\TD 1 DV: • - IVD 5Lcx7‘ 61167: .. .''b o e : 214--) MD 706 '. 3 TVD ; OP : /7 S iD 764. TVi -ub : ?ackc= `S7a7im TVD; Set. at :o1r, Site fins; 7S : -,� 1116 ; Ierfs I777 2 to 7-40 • AA-0 . 340 rreo Gl A/ IIICBARICAL Inman: 1'°n. - ?ART s'' 1 3cro` s A.nnuJ,v.s Press Test: I 1 13 m 30 zzi Comments : M ! / ' � ? ,.c, `< w. p �. . , 7 u �..; ` � y... ,.�.. �.. .� ,... - �.� .��.s = m. . � � �.s sa . KE,CHA iCAL INTECITT .T a PA ? 2 , ,t1 - -_ — - 7 Cement V o i e s : Ant. Liner G a g B 1 �,,,�,. to . Cmt vc1 Lo cove perfs ' S`7 66L 4 - couw -- -" S ov (f,44 s ,.r .. _ . rt-. . ,same ,._ -tc- ''0.'+2 • a'. .a ∎a- ..� - .,� Theoretice.1 TOC S S / M , D 7 — v4.._ 0 - 3 a Cement; I ond. Log 6fi) or No) MT'"; In AOCCC File... CBI. Eval.tmtion 4 zone above gerfs _t ro -.-, s l 29 l7 ao M. A �� e..4e�, 1 7% ( AA P. 11,a �� Ptoduo.tian Log: Type AI 1 Evalue.tion CONCLUSIONS 5€rt i1: M tT r'cZctide.O. . ?art / 2 :. e 14 ` • O-s--.Y .7 4-4l i ci .y ^ N ri �� „..././,-./, 3 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: 210 -0080 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -124 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20612 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 310 -088 4/8/2010 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 382* 382 totals (bbls): 2010 / 2nd 0 0 0 0 0 2010 / 3rd 0 0 0 0 0 2010 / 4th 0 0 0 0 0 2011 / 1st 31514 100 0 31614 24 3/8/2011 3/31/2011 CD3 -125, CD3 -198, CD3 -199 Total Ending Report is due on the 20th Volume 31514 100 382 31996 24 (bbls): of the month following the final month of the quarter. Ex: 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 1 Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: A.c _` 'L Date: 44 o tl 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 I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 0 008 Commissioner c 3_ 13 ' i f ommissioner Dan Seamount Alaska Oil & Gas Commission RFC Er ° {;: y ;, P 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 FEB 0 4 2011. +r �' & G C an so C ,, Commissioner Dan Seamount: 1 N Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 January 31, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907- 659 -7043, if you have any questions. Sincerely, , j/ MJ Loveland 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 213/2011 CD3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # , cement , pumped , cement date inhibitor sealant date ft bbls ft gal CD3- 106 50103206110000 2100010 16" NA 16" NA 7.65 1/31/2011 CD3 -110 50103205090000 2050410 4" NA 6" NA 2.13 1/31/2011 CD3 - 112 50103205270000 2060320 3" NA 16" NA 2.73 1/31/2011 CO3 - 114 50103205440000 2070330 5" _ NA 14" NA 2.55 1/31/2011 CD3 - 121 50103206150000 2100220 32" _ NA 32" - NA 27.2 1/312011 CD3 -122 50103206090000 2091530' 74" NA 74" NA 322 1/31/2011 1 124 I 50103206120000 2100080 17" NA NA 17" NA 5.1 1131/2011 CD3 -301A 50103205430100 2060170 9" 15" NA 4.25 1/312011 CD3 -302A 50103205220100 2100350 5" NA 16" NA 3.83 1/312011 CO3 - 304 50103205980000 2090280 18" NA 18" NA 5.9 1/31/2011 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: 210 -0080 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -124 2. Address: 4b. Well Status: Oil El Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20612 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal El or Continuation NI or Final ❑ 310 -088 4/8/2010 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 382* 382 totals (bbls): 2010 / 2nd 0 0 0 0 0 2010 / 3rd 0 0 0 0 0 2010 / 4th 0 0 0 0 0 2011 / 1st Total Ending Report is due on the 20th S Volume 0 0 382 382 0 (bbls): of the month following the final month of the quarter. Ex: 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): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: �,^ 1' 'Q�,(2u f( Date: Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 A Br 1AS JAN 20 2011 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA i 7 f.' /.0 ALASKA OIL AND GAS CONSERVATION COMMISSION . REPORT OF ANNULAR DISPOSAL ' :�. 'es `'F. Cx4141 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 210 -0080 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -124 2. Address: 4b. Well Status: Oil • Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20612 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 310 -088 4/8/201 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 382" totals (bbls): 2010 / 2nd 0 0 0 0 0 2010/3rd 0 0 0 0 0 2010 / 4th 0 011 / 1st Total Ending Report is due on the 20th Volume 0 0 382 0 0 (bbls): of the month following the final month of the quarter. Ex: 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): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. A ..6_ Signature: (20i Date: 19 ( 6 I L o t 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 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL � 2-010 Alaska Oil Et Cmr.;. Commission 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ A 1 / 0 1400n ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -124 2. Address: 4b. Well Status: Oil IV Gas ❑ WAG El 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20612 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal or Continuation ❑ or Final El 310 -088 4/8/2010 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 totals (bbls): 382* 2010 / 2nd 0 0 0 0 0 2010 / 3rd 2010 /4th 2011 / 1st Total Ending Report is due on the 20th Volume 0 0 382 0 0 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time El Step Rate Test El October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only I hereby certify that the foregoing is true nd correct to the best of my knowledge. Signature: A ( l 74 G /JO f d Dat e: 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 • Page 1of1 Schwartz, Guy L DOA Y (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 19, 2010 12:50 PM To: 'Walker, Jack A' Subject: RE: CD3 -124 (PTD 210 -008) I don't think you will have to resend the 407. We will correct it to reflect well status as "oil" . Next year when you convert to injection submit a 403 to get the process started.. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Walker, Jack A [mailto: Jack .A.Walker @conocophillips.com] Sent: Monday, April 19, 2010 11:39 AM To: Schwartz, Guy L (DOA) Cc: Allsup- Drake, Sharon K Subject: CD3 - 124 Guy, Sharon confirmed that we filed the CD3 -124 10-407 completion report as a Service WAG classification. Should we amend the 10-407 for CD3 -124 as we're producing it and plan to produce until next ice road season? Jack 4/19/2010 • • SlitinfE DIF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 OC1� Anchorage, AK 99510 -0360 I (3 Re: Colville River Field, Fiord Oil Pool, CD3 -124 dC Sundry Number: 310 -088 Dear Mr. Alvord: 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, 9 Daniel . Seamount, Jr. -1ij Chair DATED this day of April, 2009 :,LA Encl. �(� /, • r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 1. Operator 3. Permit to Drill Name: 2100080 ConocoPhillips Alaska 4. API Number: 50- 103- 20612 -00 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 -124 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: CD3 -115, CD3 -118, CD3 -117, CD3 -114 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None 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 1658' 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 2,003 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 - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 15 Apr - 10 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 drilling a well permited under 20 MC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) FIT Records w /LOT Graph Surf. Casing Cementing Data 0 Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. �� Signature: _ : - 6_ 0.4k Title: ' L Orl Printed Phone Name: Chip Alvord Number: 265 -6120 Date: 3 /24 //D / Commission Use Only Conditions of approval: Cow' e l r a Li/ 2 o AAC 2 5, O$ C5 LOT review and approval: `17.70 Subsequent form require / 142 3 Approval number: 3/ O ^ 1,)/1'31 APPROVED BY / Approved by: 7 COMMISSIONER THE COMMISSION . Date: 4, I �✓ 1 ( (� MOMS /A� DD t1 — D r , 1APR34Be ^41,;1,004 t � N IN �T I TI ) c1N FNVA 7s-- 4/.7 /0 Submit inDuplicate ' ? 'G° NA • • Annulus Disposal Transmittal Form - Well CD3 -114 AOGCC Regulations, 20 AAC 25.080 (b) _ 1 Designation of the well or wells to receive drilling wastes: CD3 -124 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. 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/I. (Ref. AOGCC Conservation Order No. 443, _ _March 15. 1999) 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 drilling 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 2,003 psi. See attached calculation - calculations showing how this value was determined. page. 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 anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. _ test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing 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 CD3 -124, CD3 -121, CD3 -123, CD3 -301A, CD3 -302A will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Ve on 1.0- Jan '05 Well CD3 -124 Assumptions Date 3/19/2010 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 Maximum Fluid Density to avoid Burst of Surface Casing t _ Pburst85% = PHydrostatic + PApplied - PFormation 3,043 = ( 2,469 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,469 ) MWmax = 20.4 ppg ■_ 2,469 TVD � " Surface Casing String Size 10.75 in Weight 45.5 ppf ;; to Grade L 80 rburstl00% 3,580 psi t Pburst85% 3,043 psi Depth of Shoe 2,469 ft FIT /LOT @ Shoe 15.6 ppg or 2,003 psi FIT /LOT for Annulus 14.6 ppg N Max Surf. Pressure 1,500 psi TOC Est. @ 14,100' MD 6,472' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,072 = ( 6,472 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 6,472 ) - 1,000 Z Z MWmax = 12 ppg - "Tubing 2nd Casing String Size 7.625 in 7.073 TVD D Weight 29 ppf Grade L 80 rcollapse100% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 6,472 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT /LOT Pmax allowable = ( 2,469 * .052 * 15.6 ) Pmax allowable = 2,003 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". SURFACE CASING SHOE SEPARATION FROM CD3 -124 CD3 -124 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27 386004.0 6003334.0 Iis ance Ann. from Surface csg. Surface Details @ Disp. Ann. Object Shoe X Surface csg. Surf LOT casing TVD Annular Wells AOGCC Permit # Permit Date Source well Vol. ** Start Date End Date well Coord. Shoe Y Coord. (ppg) (ft) LOT (ppg) Comments CD3 -108 __ / .- 3687 389300.3 6004986.4 MEM MIIMIIIIMMI not for annular disposal CD3 -110. CD3 -111. CD3 -1 12 CD3 -109 y 306 -020 _ CO3 -307. CD3 -302 1/20/2006 3/4/2007 3253 388917.3 6004780.2 18.0 2414 16.0 Extended to 70000bbI, exp 03/17/07 r M' WirMIM 388563.7 6004720.7 Low surface shoe test mamma= 307 - 066 - CD3 - 114, CD3 - 301 26674 3/20/2007 4/20/2007 2280 387821.0 6004710.6MM= 2469 CD3 - 112 307 - 002 , CD3 - 113, CD3 107/CD3 - 307 ME= 3/1612007® 387406.8 6004382.6 18.0 2485 15.1 Also known as CD3 -107, second annlus, CD3- 107/307 3737 389627.9 6004245.8 18.2 2479 15.3 after cut and pull operations Feb 2007 CD3-113, CD3 -118, CD3 -303, CD3 -302 308 -036 CD3 -107L1 28647 2/12/2008 5/2/2008 3032 388815.4 6004469.9 18.0 2505 15.0 CO3 - 113 307 - 067 CD3 - 316. CO3 - 316A :9b i 1/15/2008 3/20/2008=il,I8MEIMEM 6003901.1 18.0® CD3 - 114 ' _ 0 III /�� ® 6003781.8 C D3 - 301 WAN . 1111111 MallIMMINIVIIIIIMEM 388541.7 6005510.5 mem zgi® Low surface shoe test CO3 - 316A Y 308 - 127 4'4/ i /z008 CD3 - 305, 003 - 115 31881 1/11/2009 2/16/2009 2872 388868.2 6003548.0 18.0 2476 15.9 CD3 - 303 Y 308 - 426 12/15/2008 CD3 - 117 23833 2/14/2009 3/27/2009 4127 390091.0 6003906.6 18.0 2488 15.9 CD3 - 118 Y _ - J01111 ® 386456.5 6003425.3 =EU =MU ® Low surface shoe test • CD3 - 305 Y 309 - 379 12/1/2009 ® 390145.4 6003158.0 18.0 2471 14.70 CD3 - 115 Y 309 - 087 3/11/2009 CD3 - 304 20722 4/23/2009 386822.0 6003553.0 18.0 2471 13.30 CD3 - 304 Y 309 - 380 12/1/2009 IIIIIII 4787 390789.9 6003209.3 18.0 IMO= =MCI ©� �� 6003320.0 1111163111111 �0 j ' -1111•EDIMEREEI 6004126.7 =MEM 14. CD3 -124 N - -® 386004.0 6003334.0 15.9 2472 14.60 .. - - - -- - - -1 -- - - - - --_ --- - - - - -- *Lateral distance in feet, between surface casing shoes, in the X -Y plane **As of Nov 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes • • WALLIBURTDN REFERENCE INFORMATION WELL DETAILS: CD3 -124 North American Datum 1983 AlaskaZone4 - --- - - -- -- C D 3 - 12 4 Co-ordinate (N/E) Reference: Well CD3 -124, True North Ground Level: 12.50 Sperry priming Vertical (TVD) Reference: CD3 -124 49.298 (Doyon 19) +N / -S +EJ -W Northing Eastmg Latittude Longitude Slot ' 2000 — Quarter M easure Mile W d Depth Reference: CD3 -124 5/ 49.295 (Doyon 19) Calculation Method: Minimum Curvature 000 0.00 6003518 .1 71 5 2 794 7.59 70° 25' 8.091 N150° 54' 58 502 W fi CASING DETAILS 1750— 9 - Ci TVD TVDSS MD Size Name 2468.71 2419.42 3540.16 10 -3/4 10 3/4" - - 7" x 8 - 3/4" 7073.14 7023.85 17888.31 7 7" 1500— i 7002.40 6953.11 23911.00 4 -1/2 41/2" k ey s N 1250 — ti��i O loon— A - - - 7" x 8 -3/4" 9 5/8" 750— ` '''\'' ::: — _ — ' 12 -1/4" ,� 9 5/8 x 1 • 0 0 — G 9 - � `` - 9-5/8 + _ - 250 — CD3 -124 1/4 mile 10 3/4" 4.000_,....../.... 7" x 8 -3/4" t -500 o - cn -750— = C9 11.- 9 x 12 ]000- - (5) -1250— - T M Azimuths to True North Magnetic North: 21.29° el -1500— N� 1 Magnetic Field V Y Strength: 57625.1 snT G Dip Angle: 80.78° • — Date: 2/15/2010 -1750 Model: BGGM2009 -2000- -2250— - 2500 - 1 1 1 1 1 1 1 1 1 I r 1 1 1 I 11111111111111111111111111111111111111111 T F 1 T T I 1 1 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 I T T 1 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1111111111111111, -5000 - 4750 -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 West( - )/East( +) (650 ft/in) r' ConocoPhillips CD3 -124 Surface casing Well: CD3 - 124 10 3/4 ", 45.5 #, L -80, BTC -M Casing Date: 2/9/2010 Conoco Phillips Rig: Doyon 19 V�.V� � Mak*, . Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 Top of String or Top of Flange RKB to Top of Landing Ring 36.00 FMC 10 3/4" Casing Hanger 2.21 36.00 Jts 3 to 86 84 Jts 10 3/4 ", 45.5 #, L -80, Casing 3422.93 38.21 HES 10 3/4" Sure Seal II Float Collar 1.20 3461.14 Jts 1 to 2 2 Jts 10 3/4 ", 45.5 #, L -80, Casing 75.52 3462.34 Ray Oil Tools 10 3/4" Silver Bullet Float Shoe 2.30 3537.86 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 13 -1/2" TD A 3550' MD / 2472' TVD 3540.16 10 -3/4" Casing Shoe A 3540' MD / 2468.6' TVD 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 99 Joints in Pipe Shed - Run 86 / Last 13 jts. out 3540.16 3540.16 One bowspring on stop 10' above shoe and on collar of it #1. 3540.16 One bowspring on stop 10' below collar of jt #2. 3540.16 One Bowspring Centralizer per Joint 3 -15, then Every Other Joint 17 - 85 3540.16 Total 51 Bowsprings - Two Stop Collars 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 3540.16 Remarks: Drifted to 9.88" w/ plastic rabbit Up Wt 205 K Dn Wt 140 K Block Wt 75 K Supervisors: Burley / Browning • Cement Detail Report CD3 -124 t onocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/5/2010 23:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/9/2010 19:07 2/9/2010 21:11 CD3 -124 Comment Install Dowell cement head, establish circulation, stage rate f/ 3 to 7 bpm, circulate and condition mud f/ cementing. Final mud weight 9.8 ppg, PV/YP 19/19. Circulated 809 bbls total. Pump 125 bbls of 9.8 ppg mud w/ nut plug marker, then 35 bbls Biozan water w/ nut plug. Dowell pumped 5 bbls water, pressure tested lines to 3000 psi- good, bleed off pressure, drop bottom plug. Mix and pump 48.14 bbls Mud Push II spacer (10.5 ppg), pumping 6 bpm w/ 260 psi. Mix and pump 467.27 bbls (574 sx) AS lite lead cement (10.8 ppg)(4.57 cuft/sx) (21.23 gal water /sx), pumping 7.5 bpm w/ final pressure of 466 psi. Mix and pump 62.4 bbls (299 sx) Alpine tail cement (15.8 ppgj11 cuft/sx) (5.105 gal water /sx), pumping 5.5 bpm w/ final pressure of 215 psi. Shut down, then drop top plug. Dowell kick out top plug w/ 20 bbls water, pumping 6 bpm w/ 50 psi. Turn over to the rig. Rig displace cement w/ #2 mud pump, 9.8 ppg mud. Pumping 8 bpm w/ initial 270 psi. After pumping 300 bbls, final rate of 8 bpm w/ 740 psi, slowed to 4 bpm w/ 480 psi initial/ 510 psi final, bumped plug at calculated strokes (3112strokes) (312.75 bbls) to 1260 psi. Held pressure f/ 5 minutes. CIP @ 2111 hrs 2/9/2010. Note: Reciprocated until 10.8 ppg cement was back to surface. Landed on hanger @ 2053 hrs (191 bbls mud displaced). Circulated 118 bbls of pond 1n R ppg cement to surface. Check floats- OK. Rig down Dowell cementing equipment. Observed fluid in the stack falling slowly. Allow cement in riser to fill below hanger for 45 minutes after bumping plug. Drop ,of aoorox 9 feet = 1.23 bbls. Cement Stages Stage # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Surface Casing Cement Cement 10 -3/4" surface 36.0 3,540.2 Yes 118.0 Yes Yes 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) 6 4 6 510.0 1,260.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 3,454.0 Drill Bit 9 7/8 Comment Install Dowell cement head, establish circulation, stage rate f/ 3 to 7 bpm, circulate and condition mud f/ cementing. Final mud weight 9.8 ppg, PV/YP 19/19. Circulated 809 bbls total. Pump 125 bbls of 9.8 ppg mud w/ nut plug marker, then 35 bbls Biozan water w/ nut plug. Dowell pumped 5 bbls water, pressure tested lines to 3000 psi- good, bleed off pressure, drop bottom plug. Mix and pump 48.14 bbls Mud Push II spacer (10.5 ppg), pumping 6 bpm w/ 260 psi. Mix and pump 467.27 bbls (574 sx) AS lite lead cement (10.8 ppg)(4.57 cuft /sx) (21.23 gal water /sx), pumping 7.5 bpm w/ final pressure of 466 psi. Mix and pump 62.4 bbls (299 sx) Alpine tail cement (15.8 ppg)(1.17 cuft/sx) (5.105 gal water /sx), pumping 5.5 bpm w/ final pressure of 215 psi. Shut down, then drop top plug. Dowell kick out top plug w/ 20 bbls water, pumping 6 bpm w/ 50 psi. Turn over to the rig. Rig displace cement w/ #2 mud pump, 9.8 ppg mud. Pumping 8 bpm w/ initial 270 psi. After pumping 300 bbls, final rate of 8 bpm w/ 740 psi, slowed to 4 bpm w/ 480 psi initial/ 510 psi final, bumped plug at calculated strokes (3112strokes) (312.75 bbls) to 1260 psi. Held pressure f/ 5 minutes. CIP @ 2111 hrs 2/9/2010. Note: Reciprocated until 10.8 ppg cement was back to surface. Landed on hanger @ 2053 hrs (191 bbls mud displaced). Circulated 118 bbls of good 10.8 ppg cement to surface. Check floats- OK. Rig down Dowell cementing equipment. Observed fluid in the stack falling slowly. Allow cement in riser to fill below hanger for 45 minutes after bumping plug. Drop of approx 9 feet = 1.23 bbls. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Viscosified Water 35.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push II 48.1 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Arctic Set Lite 36.0 2,897.8 574 G 467.3 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.57 21.23 10.80 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.5 %BWOC Additive Type Concentration Conc Unit label D046 AntiFoam 0.6 %BWOC Page 1/2 Report Printed: 3/19/2010 • . °MIN Cement Detail Report CD3 -124 ConocoPhil lips String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/5/2010 23:00 Additives Additive Type Concentration Conc Unit label D079 Extender 1.5 %BWOC Additive Type Concentration Conc Unit label D124 Extender 50.0 %BWOW Additive Type Concentration Conc Unit label D044 Freeze Suppressant 9.0 %BWOC Additive Type Concentration Conc Unit label D053 Thixotropic 30.0 %BWOC Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surface Tail 2,897.8 3,540.2 299 62.4 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 2/2 Report Printed: 3/19/2010 • • • Security Level: AK Development Daily Drilling Report CD3 -124 Report Number: 5 ConocoPhtl li PS Rig: DOYON 19 Report Date: 2/9/2010 AFE Type NetavwWlO # Total AFE Sup 10274673 12,525,001.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -124 Development FIORD NECHELIK 3.42 5.0 0.00 3,550.0 3,550.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 6,203.07 70,013.66 719,567.07 1,688,800.66 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/5/2010 2/6/2010 35.26 32.59 2.67 3/10/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 3,540.2ftKB Ops and Depth @ Morning Report 24hr Forecast Pick up/ make up/ stand back 5" drill pipe. Nipple down, nipple up, pick up / stand back 5" drill pipe, test BOPE, make up BHA #2, run in the hole, test casing, drill float equipment. Last 24hr Summary Continue to POOH f/ 3188', work through tight spot @ 1255, circulate, continue to POOH, PJSM, L/D BHA #1, clean floor, RU to run 10 -3/4" csg, PJSM, Run 10 -3/4" 45.5 ppf L -80 BTCM csg to 115', lay down jt #4(couldn't get pass 115'), circ w/ Frank's fillup tool- washing down f/ 115' to 155', continue to run csg to 1793', CBU, con't running casing f/ 1793' to 3540', rig down Frank's tool, install Dowell cement head, establish circulation, stage rate f/ 3 to 7 bpm, circ and cond mud f/ cementing, 809 bbls pumped. Pump 125 bbls of 9.8 ppg mud w/ nut plug marker, then 35 bbls Biozan water w/ nut plug. Dowell pumped 5 bbls water, pressure tested lines to 3000 psi- good, bleed off pressure, drop bottom plug. Mix and pump 48.14 bbls Mud Push II spacer (10.5 ppg), pumping 6 bpm w/ 260 psi. Mix and pump 467.27 bbls (574 sx) AS lite lead cement (10.8 ppg)(4.57 cuft/sx) (21.23 gal water /sx), pumping 7.5 bpm w/ final pressure of 466 psi. Mix and pump 62.4 bbls (299 sx) Alpine tail cement (15.8 ppg)(1.17 cuft/sx) (5.105 gal water /sx), pumping 5.5 bpm w/ final pressure of 215 psi. Shut down, then drop top plug. Dowell kick out top plug w/ 20 bbls water, pumping 6 bpm w/ 50 psi. Turn over to the rig. Rig displace cement w/ #2 mud pump, 9.8 ppg mud. Pumping 8 bpm w/ initial 270 psi. After pumping 300 bbls, final rate of 8 bpm w/ 740 psi, slowed to 4 bpm w/ 480 psi initial/ 510 psi final, bumped plug at calculated strokes (3112strokes) (312.75 bbls) to 1260 psi. Held pressure f/ 5 minutes. CIP @ 2111 hrs 2/9/2010. Note: Reciprocated until 10.8 ppg cement was back to surface. Landed on hanger @ 2053 hrs (191 bbls mud displaced). Circulated 118 bbls of good 10.8 ppg cement to surface. Check floats- OK. Rig down Dowell cementing equipment. Observed fluid in the stack falling slowly. Allow cement in riser to fill below hanger for 45 minutes after bumping plug. Drop of approx 9 feet = 1.23 bbls. Flush stack. Pull, then lay down the FMC 10 -3/4" landing joint. Prep to ND. General Remarks Weather Head Count No Spills / No Accidents. Run one engine w/ hi- line power. -8 °, WC -30 °, Wind NE @ 16 Mph, 2 -1/2 mile 50.0 vis Swervisor Title Dave Burley, Rig Supervisor Rig Supervisor Granvii llle Rig Supervisor Rig Supervisor � End Dur iktre depth Start Depth End Time Tkne (hrs) ptase Op Code ActMty Code P-T -X Trbi t 'Obi Class. (f#03) (WS) Operation 00:00 01:30 1.50 SURFAC DRILL TRIP P 3,188.0 1,255.0 Continue to POOH on elevators from 3,188' to 1,255' - pulled 20K over @ 1,255' - Free PUW 130K SOW 120K 01:30 02:15 0.75 SURFAC DRILL CIRC P 1,255.0 1,189.0 Establish circulation - staged pumps up to 500 gpm / 1040 psi / 60 rpm - Worked pipe from 1285' to 1189' circulated hole clean - slight amount of cuttings across shakers 02:15 03:30 1.25 SURFAC DRILL TRIP P 1,189.0 909.0 POOH on elevators from 1,189' to 909' - PUW 120K SOW 110K - flow check well, static 03:30 04:00 0.50 SURFAC DRILL TRIP P 909.0 74.0 POOH on elevators from 909' to 74' - stood back HWDP and Flex collars 04:00 05:15 1.25 SURFAC DRILL PULD P 74.0 0.0 PJSM: LD BHA #1 - LD bit, UBHO, FS, Antenna sub, Index sub, EM collar, stab & motor 05:15 05:45 0.50 SURFAC DRILL PULD P 0.0 0.0 Clear tools from rig floor - clean up trip mess 05:45 07:00 1.25 SURFAC CASING RURD P 0.0 0.0 PJSM - rig up to run 10 3/4" casing 07:00 07:15 0.25 SURFAC CASING SFTY P 0.0 0.0 PreJob safety and Opts meeting on running casing 07:15 08:15 1.00 SURFAC CASING RNCS P 0.0 115.0 Run 10 3/4 ", 45.5 ", L -80 BTC -M casing - Silver bullet FS, 2 joints, Halliburton FC, 2 jts of casing - could not pass 115' - Latest BOP Test Data Dabs I Comment Page 1/4 Report Printed: 3/19/2010 Security Level: AK Development Daily Drilling Report CD3 -124 Report Number: 5 Conoc©Phil lips Rig: DOYON 19 Report Date: 2/9/2010 Time Log Start End Our tene Depth Start Depth End Time Time (hrs) phase Op Code Activity Cafe P T`X Trbl Code Trill Clese. ( ) MKS) Operation 08:15 09:00 0.75 SURFAC CASING CIRC T Hole Other 115.0 115.0 Laid down joint #4 - Confirmed ability to Conditions circulate through fill up tool - Stabbed into joint #3 - established circ and checked floats, ok - MU jnt#4 09:00 12:15 3.25 SURFAC CASING RNCS P 115.0 1,793.0 Wash down from 115' to 155' - 3.5 bpm / 180 psi - slight resistance for ten feet - no furhter problem - Continue to run 10 3/4" casing from 155' to 1793' (44 jts total) PUW 140K SOW 125K 12:15 12:45 0.50 SURFAC CASING CIRC P 1,793.0 1,793.0 Establish circulation 3.5 bpm / 280 psi - stage pumps up to 6.1 bpm CBU - FCP= 470 psi PUW 140K SOW 125K 12:45 15:15 2.50 SURFAC CASING RNCS P 1,793.0 3,540.0 Run 10 3/4" casing from 1,793' to 3,497 (86 jts. total) - MU FMC fluted casing hanger and Landing joint - land casing with shoe @ 3,540', FC @ 3,461' 15:15 16:00 0.75 SURFAC CEMENT RURD P 3,540.0 3,540.0 RD fill up tool - Blow down top drive - Install cement head and lines 16:00 18:15 2.25 SURFAC CEMENT CIRC P 3,540.0 3,540.0 Establish circulation, pumping 3 bpm w/ 300 psi. Stage pumps up to 7.0 bpm w/ 380 psi. Pumped a total of 809 bbls. Final mud properties: weight 9.8 ppg, PV/YP 19/19. Note: Held pre job safety meeting on cement job while circulating. Reciprocated 15 to 20'. 18:15 18:45 0.50 SURFAC CEMENT CIRC P 3,540.0 3,540.0 Rig pumped 125 bbls of 9.8 ppg mud with nut plug marker, followed with 35 bbls Biozan with nut plug marker (8.5 ppg). Pumping 6 bpm w/ 310 psi. Reciprocated 15' to 20'. PU wt 200k, SO wt 155k. 18:45 20:24 1.65 SURFAC CEMENT PUCM P 3,540.0 3,540.0 Dowell pumped 5 bbls water, pressure tested lines to 3000 psi- good, bleed off pressure, drop bottom plug. Mix and pump 48.14 bbls Mud Push II spacer (10.5 ppg), pumping 6 bpm w/ 260 psi. Mix and pump 467.27 bbls (574 sx) AS lite lead cement (10.8 ppg)(4.57 cuft/sx) (21.23 gal water /sx), pumping 7.5 bpm w/ final pressure of 466 psi. Mix and pump 62.4 bbls (299 sx) Alpine tail cement (15.8 ppg)(1.17 cuft/sx) (5.105 gal water /sx), pumping 5.5 bpm w/ final pressure of 215 psi. Shut down, then drop top plug. 20:24 20:30 0.10 SURFAC CEMENT DISP P 3,540.0 3,540.0 Dowell kick out top plug w/ 20 bbls water, pumping 6 bpm w/ 50 psi. Turn over to the rig. Page 2/4 Report Printed: 3/19/2010 • Security Level: AK Development Eiggai Daily Drilling Report CD3 -124 Report Number: 5 ConocoPhil l ips Rig: DOYON 19 Report Date: 2/9/2010 Time L.og Start End Our Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T -X Trial Code Try Cams. MS) ( ) Operation 20:30 21:15 0.75 SURFAC CEMENT DISP P 3,540.0 3,540.0 Rig displace cement w/ #2 mud pump, 9.8 ppg mud. Pumping 8 bpm w/ initial 270 psi. After pumping 300 bbls, final rate of 8 bpm w/ 740 psi, slowed to 4 bpm w/ 480 psi initial/ 510 psi final, bumped plug at calculated strokes (3112strokes) (312.75 bbls) to 1260 psi. Held pressure f/ 5 minutes. CIP @ 2111 hrs 2/9/2010. Note: Reciprocated until 10.8 ppg cement was back to surface. Landed on hanger @ 2053 hrs (191 bbls mud displaced). Circulated 118 bbls of good 10.8 ppg cement to surface. 21:15 22:00 0.75 SURFAC CEMENT RURD P 3,540.0 3,540.0 Check floats- OK. Rig down Dowell cementing equipment. Observed fluid in the stack falling slowly. Allow cement in riser to fill below hanger for 45 minutes after bumping plug. Drop of approx 9 feet = 1.23 bbls. 22:00 23:00 1.00 SURFAC DRILL PULD P 3,540.0 0.0 Flush stack. Pull, then lay down the FMC 10 -3/4" landing joint. 23:00 00:00 1.00 SURFAC DRILL OTHR P 0.0 0.0 Clean and clear rig floor. Pull the mouse hole to prepare for nippling down. Mud Check Data YP Cat - Get (1Os) Gel (10m) - Gel (Ian) HTHP Pat Density Temp Solids, Corr. Type Depth (ftKB) Dens (Waal) Ms (stgt) PV Calc tp) SWOOP) (k8 X (bf110OfP) (lbfl/tooft*) MBT (IblbM) (n LI30min) pH ( (%) Spud Mud 3,550.0 9.70 46 8.0 11.0 4.0 4.0 5.000 25.0 9.1 9.0 Injection Fluid Fluid Source Pram Lease (bbl) Vendor Manifest Number Note Diesel CD3 -124 30.0 CD3 -304 Freeze protect Water CD3 -124 150.0 CD3 -304 Flush Water Based Mud CD3 -124 780.0 CD3 -304 Spud mud Wellbores Wellbore Name Wellbore API /UWI CD3 -124 501032061200 Section Site (In) Act Top (ftRB) Act Btm (ftKB) Start Date End Date CONDI 24 37.0 114.0 SURFAC 13 1/2 114.0 3,550.0 2/6/2010 2/8/2010 INTRM1 9 7/8 3,550.0 17,900.0 2/11/2010 2/17/2010 PROD1 6 3/4 17,900.0 23,981.0 2/28/2010 3/5/2010 Page 3/4 Report Printed: 3/19/2010 Security Level: AK Development Daily Drilling Report CD3 -124 Report Number: 5 ConocoPhillips Rig: DOYON 19 Report Date: 2/9/2010 Casing Strings String CO String Wt Casing Run (in (Ibs/ t) string Grade set Depth (ftKB) Comment Surface 2/9/2010 10 3/4 45.50 L80 3,540.2 Run 10 3/4 ", 45.5 ", L -80 BTC -M casing - Silver bullet FS, 2 joints, Halliburton FC, 2 jts of casing - could not pass 115' - Laid down joint #4 - Confirmed ability to circulate through fill up tool - Stabbed into joint #3 - established circ and checked floats, ok - MU jnt#4. Wash down from 115' to 155' - 3.5 bpm / 180 psi - slight resistance for ten feet - no furhter problem - Continue to run 10 3/4" casing from 155' to 1793' (44 jts total) PUW 140K SOW 125K. Establish circulation 3.5 bpm / 280 psi - stage pumps up to 6.1 bpm CBU - FCP= 470 psi PUW 140K SOW 125K. Run 10 3/4" casing from 1,793' to 3,497 (86 jts. total) - MU FMC fluted casing hanger and Landing joint - land casing with shoe @ 3,540', FC @ 3,461'. RD fill up tool - Blow down top drive - Install cement head and lines. PU wt 200k, So wt 155k. Circ and condition mud, pumped 809 bbls. Recip 15 -20'. Cement Surface Casing Cement - Started an, 2/9/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 -124 Surface, 3,540.2ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.0 3,540.2 4 510.0 F=luid Class Amount (sacks) V (be) Density (ibigaI) Yield (ft'/sack) Est Top (ftKB) Est Btm (ftKB) Viscosified Water 35.0 8.50 Mud Push II 48.1 10.50 Arctic Set Lite G 574 467.3 10.80 4.57 36.0 2,897.8 Alpine Surface Tail 299 62.4 15.80 1.17 2,897.8 3,540.2 Page 4/4 Report Printed: 3/19/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -124 Rig: Doyon 19 'Date: 1 2/11/2010 Volume Input Volume /Stroke - Pump Rate: Drilling Supervisor: ' Dave Burley/ Granville Rizek 'Pump used: #2 Mud Pump V 'Strokes 0.1005 Bbls /strk 1r Strk/min Type of Test: Casing shoe Test LOT /FIT V Pumping down annulus and DP. W Casing Test Pressure Integrity Test Hole Size: 9 - 7/8" V Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 36.0IFt 3540.2IFt -MDI 2468.6IFt -TVD 3570.0IFt -MD 12478.6IFt -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 10 -3/4" 45.5 # /Ft L -80 BTC I V 0 0 3510 0 0.00 1030 Casing Test Pressure IntegrityTesl 2 1 3510 2 90 0.25 1000 Mud Weight: 9.6 ppg Mud Weight: j .6 ppg 4 200 2 3510 4 160 0.50 980 Mud 10 min Gel: 25.0 Lb /100 Ft2 Mud 10 min Gel: 32.0 Lb /100 Ft2 6 360 3 3510 6 290 1.00 930 Test Pressure: 3500.0 psi Rotating Weight: Lbs 8 540 4 3510 8 410 1.50 900 Rotating Weight: ###### Lbs Blocks /Top Drive Weight: 74000.0 Lbs 10 710 5 3500 10 540 2.00 890 Blocks /Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 860 6 3500 12 620 2.50 880 Estimates for Test: 4.2 bbls Estimates for Test: 1078 psi 1.3 bbls 14 970 7 3500 14 710 3.00 870 ■ II i • 16 1100 8 35( 16 770 3.50 860 EMW = Leak -off Pressure + Mud Weight = 770 + 9 6 PIT 15 Second 18 1230 9 3500 18 830 4.00 850 0.052 x TVD 0.052 x 2469 Shut -in Pressure, psi 20 1370 10 3500 20 880 4.50 850 EMW at 3540.16 Ft -MD (2468.61 Ft -TVD) = 15.6 ppg 1000 22 1510 15 3490 22 940 5.00 850 4000 - - Lost 20 psi during test, held 24 1660 20 3490 24 1000 5.50 840 99.4% of test pressure. - 26 1800 25 3490 1050 6.00 840 3500 aWyWr • • • • 28 1950 30 3490 1070 6.50 830 now - _ 30 2110 7.00 830 3000 - - ■ r 32 2270 7.50 820 34 2430 8.00 820 AIM w 2500 . - 36 2600 8.50 820 ce - - i 38 2760 9.00 820 2000 • , 0 2910 9.50 820 W >. 3090 10.00 820 W AINIMININ CL 1500 - 4 3270 46 3430 1000 �� - ■_ 47 35 i 500 0 0 1 2 3 4 5 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume . CASING TEST -0-LEAK -OFF TEST O PIT Point Pumped Bled Back Pumped Bled Back 4.7 Bbls I Bbls 2.7 Bbls Bbls Comments: 1 k.,u3- 'L.+ udslrl 9 drlU ri 1 L- 1 1-LU I u.xis Summary • CD3 -124 7 -5/8" Intermediate Casing Well: CD3 - 124 7- /8" 29.7 ppf L -80 BTC -m casing Date: 2/23/2010 f illips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 Top of String or Top of Flange Rig floor to lower lockdown screws 33.75 FMC 7.625" fluted hanger (10.38" OD) 1.00 33.75 7 -5/8" 29.7 ppf L -80 pup pin x pin below hanger 2.17 34.75 Jts 215 to 42C 206 Jts 7 - 5/8" 29.7 ppf L - BTC - casing 8744.53 36.92 HES 7 - 5/8" Stage Collar 2.39 8781.45 Jts 4 to 214 211 Jts 7 - 5/8 ", 29.7ppf, L - 80, BTC - Casing 8972.58 8783.84 7 -5/8" HES Shut -off Baffle Collar 1.37 17756.42 Jts 3 to 3 1 Jts 7 -5/8 ", 29.7ppf, L -80, BTC -m Casing 43.48 17757.79 7 -5/8" HES Sure Seal II Float Collar w/ By -Pass Baffle Adapter 1.00 17801.27 Jts 1 to 2 2 Jts 7 -5/8 ", 29.7ppf, L -80, BTC -m Casing 83.91 17802.27 7 -5/8" Ray Oil Tools " Silver Bullet" Float Shoe 2.13 17886.18 Bottom of shoe »> 17888.31 9 -7/8" Hole TD A 17,900' MD / 7,074.67' TVD, Hole angle 82.65 deg 17888.31 7 -5/8" Shoe A 17888.31' MD / 7073.17' TVD/ Hole angle 82.65 deg 17888.31 17888.31 Total of 69 Straight Blade centralizers (7 -5/8" x 9- 1/16 ") - 3 Stop Collars 17888.31 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 17888.31 17888.31 Total of 69 Volant Hydoform centralizers (7 -5/8" x 9 -3/8 ") 17888.31 Jt #2 thru #70 17888.31 1 Hydroform centralizer w/ stop 10' below FC -Jt. #2 17888.31 1 Hydroform centralizer w/ stop 10' above pin -Jt. #3 17888.31 1 Hydroform centralizer per jt floating on it #4 thru #70 17888.31 17888.31 17888.31 1 Straight Blade centralizer per jt on jts #214 to #240 floating 17888.31 17888.31 1 Straight Blade centralizer on 3 jts # 340 - #342 floating 17888.31 1 Straight Blade centralizer every other jt #344 to #418 floating. 17888.31 17888.31 17888.31 17888.31 17888.31 Planned: 425 jts in pipe shed / 420 jts to run. 17888.31 5 joints left in the shed 17888.31 Remarks: Drifted w/ 6.75" plastic rabbit. Up Wt 385 K Jet Lube Run N Seal dope. Dn Wt 160 K Average make up torque = 9400 Ft Ibs Block Wt 75 K MU Toss 4 -11/16 to 4 -3/4 ". Collar length 10 -1/2 ". Collar OD 8.57" Supervisors: Fred Herbert/ Granville Rizek 0 • + Cement Detail Report CD3 -124 ConocoPhil lips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 2/5/2010 23:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/23/2010 13:45 2/23/2010 17:05 CD3 -124 Comment Cement Stages Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Intermediate Casing Primary 14,100.0 17,900.0 Yes 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) 4 6 6 1,090.0 590.0 Yes 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 152.2 Bbls of 15.8 PPG Class G Cement - CIP @ 1705 Cement Fluid & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 14,100.0 17,900.0 705 G 146.0 Yield (fP /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 6.00 Additives Additive Type Concentration Conc Unit label Retarder B155 0.11 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Stage # 2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Intermediate Casing 2nd Zone Isolation 7,162.0 8,783.8 Yes No Yes Stage 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) 4 6 6 1,600.0 300.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 62.1 Bbls of 15.8 PPG Class G Cement Through HES Stage Collet @ 8783' MD Cement Fluid & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 7,162.0 8,783.8 299 G 62.1 Yield (ft'/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 4.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) S002 0.8 %BWOC Page 1/1 Report Printed: 3/19/2010 • • Security Level: AK Development Daily Drilling Report CD3 -124 t cxiocoPhilll Report Number: 19 Rig: DOYON 19 Report Date: 2/23/2010 AFE Type Network/ID # Total AFE +Sup 10274673 12,525,001.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -124 Development FIORD NECHELIK 17.42 19.0 0.00 17,900.0 17,900.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,315.64 766,947.24 1,401,524.64 6,870,035.24 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/5/2010 2/6/2010 35.26 32.22 3.04 3/10/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 17,888.3ftKB Ops and Depth @ Morning Report 24hr Forecast UD 5" DP f/ the Derrick UD 5" DP - P/U 4" DP Last 24hr Summary CBU X 1.5 - Continue to Run Casing t/ 15,495' MD - CBU X 1.5 - Continue to Run Casing t/ 17,845' MD - M/U Hanger and Land Casing w/ Shoe @ 17,888' MD - R/U Cement Head - Circ & Condition Mud Prior to First Stage Cement - Cement First Stage w/ 152.2 Bbl of 15.8 PPG Class G Cement - Test Floats (GooD) - Open HES Stage Collar - Cement 2nd Stage w/ 62.2 Bbl of 15.8 PPG Class G Cement - Close Collar and Verify Closure - R/D Casing Running and Cementing Equipment - Set Packoff and Test t/ 5,000 Psi f/ 10 Minutes - Change 7 5/8" Rams to 3 1/2" by 6" Variable Rams General Remarks Weather Head Count No Accidents / No Spills -16 °, WC -32 °, Overcast, Wind NE @ 7 Mph 50.0 Supervisor Title Fred Herbert, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Patrick Reilly, Drilling Engineer Drilling Engineer Ryan Robertson, Drilling Engineer Drilling Engineer Time Log Start End Dur Terre Depth Start Depth End Time Time (Ixs} phase Op Code :Aogvity Code P-T-X TM! Code Trig Class. (ftKB} (ftKB) Operation 00:00 02:15 2.25 INTRM1 CASING CIRC P 13,585.0 13,585.0 Circulate 1.5+ bottom's up, 810 bbls. Stage up f/ 2 bpm w/ 400 psi, 4 bpm w/ 430 psi to 7 bpm w/ 680 psi, 26% Totco flow out going down. After Circulating: Down wt 165k w/ pump, 163k w/o pump. PU wt 290K 02:15 04:30 2.25 INTRM1 CASING RNCS P 13,585.0 15,495.0 Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 13585' to 15495' (365 jts in the hole). Obtain PU & SO wt's per rig engineer. 04:30 07:00 2.50 INTRM1 CASING CIRC P 15,495.0 15,495.0 Circulate 1.5 bottom's up, 890 bbls. Stage up f/ 2 bpm w/ 430 psi to 7 bpm w/ 700 psi. 07:00 10:00 3.00 INTRMI CASING RNCS P 154,95... 17,888.0 Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 15495' to 17845' (420 jts in the hole). Obtain PU & SO wt's per rig engineer. Make up FMC 7 -5/8" casing hanger w/ landing joint. RIH and land on hanger w/ shoe @ 17888.31' Final P/U 385, S/O 160 10:00 10:30 0.50 INTRMI CEMENT RURD P 17,888.0 17,888.0 L/D Franks Fill -Up Tool - Blow Down the Top Drive & M/U the Cement Head 10:30 13:30 3.00 INTRM1 CEMENT CIRC P 17,888.0 17,888.0 Circ & Condition Mud Prior to First Stage Cement - ICP 320 Psi @ 1 BPM FCP 730 Psi @ 7 BPM 13:30 13:45 0.25 INTRM1 CEMENT SFTY P 17,888.0 17,888.0 PJSM on Cementing 7 5/8" Casing Latest BOP Test Data Dam j Camera 2/10/2010 i Witness of test waived by AOGCC inspector Jeff Jones. Page 1/3 Report Printed: 3/19/2010 Security Level: AK Development Daily Drilling Report CD3 -124 c4rlocoPhiutps Report Number: 19 Rig: DOYON 19 Report Date: 2/23/2010 Time Log Start End Our Time Depth Start Depth End Time Time (hrs) phi Op Code Acdyity Cade P - T - x Trbt Code Trbl Class. MKS) MKS) Operation 13:45 17:15 3.50 INTRM1 CEMENT 'CMNT P 17,888.0 17,888.0 Cement Casing Shoe w/ Dowell Unit as Follows: Pump 5 Bbl CW 100 - Pressure Test Lines t/ 3700 Psi - Pump 35 Bbl CW 100, 40 Bbl 11.5 PPG Mud Push II, Drop Bottom Plug, 152 Bbl 15.8 PPG Cement, Drop Closing Plug, Pump 20 Bbl Water, then Displace Cement w/ Rig Pumps - Bump Plugs @ 795.6 Bbl of Mud Pumped - Pressure Up and Hold 1090 Psi f/ 5 Minutes - Check Floats (Good) - Load Stage Collar Closing Plug in CMT Head - CIP 1705 hrs 17:15 18:45 1.50 INTRM1 CEMENT CIRC P 17,888.0 17,888.0 Pressure Casing Up t/ 3400 Psi to Open HES Stage Collar w/ Rig Pumps 18:45 19:00 0.25 INTRMI CEMENT SFTY P 17,888.0 17,888.0 PJSM on Second Stage Cement Job 19:00 20:45 1.75 INTRM1 CEMENT CMNT P 17,888.0 17,888.0 Perform Second Stage Cement Job as Follows: Pump 30 Bbl CW 100, 30 Bbl 11.5 PPG Mud Push II & 62.1 Bbl 15.8 PPG Cement, Drop Closing Plug, Pump 20 Bbls Water the Displaced Cement w/ 383.4 Bbl 9.9 PPG Mud - Closing Plug on Seat - Pressure Up t/ 1600 Psi - Bled Off Trapped Pressure & Confirmed Stage Collar is Closed - CIP @ 2027 Hrs 20:45 22:00 1.25 INTRM1 CEMENT RURD P 17,888.0 17,888.0 Blow Down Lines - R/D Cement Head - L/D 7 5/8" Landing Jt, Cement Head, Long Bales & Casing Elevators 22:00 22:30 0.50 INTRM1 WHDBOP SEQP P 17,888.0 17,888.0 Pull Wear Ring - Install 7 5/8" Casing Pack Off 22:30 22:45 0.25 INTRMI WHDBOP PRTS P 17,888.0 17,888.0 Test Pack Off t/ 5,000 Psi f/ 10 Minutes 22:45 23:15 0.50 INTRM1 DRILL OTHR P 17,888.0 17,888.0 Clean & Clear Rig Floor - Clean out Drip Pan Under Rotary 23:15 23:30 0.25 INTRM1 WHDBOP SFTY P 17,888.0 17,888.0 PJSM on Changing 7 5/8" Rams t/ 3 1/2 X 6 Inch Variable Rams 23:30 00:00 0.50 INTRMI WHDBOP SEQP P 17,888.0 17,888.0 Remove 7 5/8" Rams Mud Check Data YP Cate Get - Get (10m) Gel (3Om) HTHP Flit Density Temp Solids, Corr. Type Depth (ftKB) Dena (1 'get) Mrs (skit) PV Cale (op) pbf /1 ( t1t0°P (Ebft1 OW/10Oft MBT (it i) (mL/3Omin} pH (°F) (%) LSND w/ 17,888.0 9.90 47 12.0 20.0 10.0 14.0 16.000 25.0 9.9 10.5 Inhibycol LSND w/ 17,900.0 10.00 44 11.0 18.0 7.0 10.0 12.000 25.0 9.5 10.5 Inhibycol Injection Fluid Fluid Source From Lease (bbi) Destinsdbm Vendor Manifest lumber Note Diesel CD3 -124 10.0 CD3 -304 Injectivity Test Drilling Mud WBM CD3 -124 334.0 CD3 -304 Drilling Mud WBM CD3 -124 325.0 CD3 -304 Fresh Water CD3 -124 109.0 CD3 -304 Weflbores Wellbore Name Wellbore API /UWI CD3 -124 501032061200 Section Size (in) Act Top (fdkB) Act Btm (ftKB) Start Date End Date C0NDI 24 37.0 114.0 SURFAC 13 1/2 114.0 3,550.0 2/6/2010 2/8/2010 INTRMI 9 7/8 3,550.0 17,900.0 2/11/2010 2/17/2010 Page 2/3 Report Printed: 3/19/2010 • Security Level: AK Development y[` Daily Drilling Report CD3 -124 Report Number: 19 CcxtocoPhii I I pS Rig: DOYON 19 Report Date: 2/23/2010 Section Site (in) Ad Top (ftKB) Act Btm (ftKB) Start Date End Date PROD1 6 3/4 17,900.0 23,981.0 2/28/2010 3/5/2010 Casing Strings String OD String Wt Casing n Run Date (fn) (Wm) SIMI; Set Depth (ftKB) Comment Intermediate 2/23/2010 7 5/8 29.70 L -80 17,888.3 Cement Intermediate Casing Cement - Started @ 2/23/2010. Type Wellbore Cemented Str Cement Evaluation Results casing CD3 - 124 Intermediate, 17,888.3ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 14,100.0 17,900.0 6 1,090.0 Fluid Class /mint ( ) V (bbl} (Ibtgat) Yield (ft' /sack) Est Top (ftKB) Est Btm (ftKB) Tail Cement G 705 146.0 15.80 1.16 14,100.0 17,900.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Intermediate Casing 2nd Stage 7,162.0 8,783.8 6 1,600.0 Fluid Class Amen (sacks) V (bbl) Density Oh/gal) Yietd (dIsack) Est Top (ftKB) Est Btm (ftKB) Tail Cement G 299 62.1 15.80 1.16 7,162.0 8,783.8 Page 3/3 Report Printed: 3/19/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -124 Rig: Doyon 19 'Date: I 2/24/2010 I Volume Input I Pump Rate: Drilling Supervisor: I Browning 'Pump used: Cement Unit Barrels Bbls /Strk 0.75 Bbl /min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy v Pumping down annulus. V - Casing Test Pressure Integrity Test Hole Size: 9 - 7/8" w Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 36.0IFt 3540.0IFt -MDI 2468.61Ft -TVD 7162.01Ft -MD 13677.01Ft -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 10 -3/4" 45.5 # /Ft L -80 BTC V I 0 0 19 0.00 Changes for Annular Adequacy Tes I Pressure IntegrityTest 1 0.5 99 0.25 Enter outer casing shoe test results in comments Mud Weight. 9.9 ppg 2 1 123 0.50 Casing description references outer casing string Inner casing OD 7.6 In. 3 1.5 148 1.00 Hole Size is that drilled below outer casing. 9.9 4 2 177 1.50 Use estimated TOC for Hole Depth 5 2.5 202 2.00 435 4 , Enter inner casing OD at right. Desired PIT EMW: ppg 6 3 230 2.50 431 Estimates for Test: -1271 psi -1.3 bbls 7 3.5 25CC 3.00 427 L v1 8 4 273 3.50 424 609 +9.9 EMW = Leak-off Pressure + Mud Weight _ PIT 15 Second 9 4.5 298 4.00 422 0.052 x TVD 0.052 x 2469 Shut -in Pressure, p sl 10 5 318 4.50 420 EMW at 354 Ft -MD (2468.6 Ft -TVD) = 14.6 517 15 5.5 337 5.00 418 loon - 20 6 360 5.50 415 25 6.5 377 6.00 413 30 7 400 6.50 411 7.5 417 7.00 409 8 438 7.50 407 8.5 454 8.00 405 w n 9 475 8.50 403 eL - 9.5 490 9.00 10 514 9.50 500 co L ? 0.5 527 10.00 w 1 545 a • • 11.5 563 12 577 12.5 593 ,3 609 14 587 15 556 o 16 538 0 2 4 6 8 10 12 14 16 18 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume TEST -LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls IBbls 16.0 Bbls IBbls Comments: Cu3- 'Lg. ' visposdI i esi.xis Summary ( TOM and Shannon, You. have requested tp di ?:pose of "new - product" clean tp fluids from the routine mixing of baud and cement Alpine as well as .the clean up fluids resulting from cleaning out the tanks.at the mud plant in preparation for using oil base scud. • The Commission had previously approved disposing Of the 'new product" clean up • fluids via annular disposal at CD 1 pad. Due to the geological setting at Alpine, Class 1 and Class 2 disposal options are Limited.- Phillips' prcdcdestsor, JRCO, had established the limitation of d ,spcteal op'tii ris to the Cor; nis. ion's satisfaction and annular diavosal visas'aprrove t as ' • ti7e practical and environmental alternative. In the requests the waste fluids are no different than previously approved and • . aril the result of the..bngoing deve1.op *eat activ_i.ties at Alpine. The Commissioners have author,i,zed me to send you th_t5 message. ay copy of this • email, Phillips is authorized to dispose oC clean up fluids •as described in you'. email. • Please call with any gUestions. 'Cam Maunder, PE Sr. Petroleum Engineer • € ( AMCC ALP 'Env Coors. wrote?.: • > Dear i'L'. Maunder, • } As noted in the attached email, Tom Manson previously requested > authorization to .diApoee• of new- product clean un fluids such. as cement r rinsate, and mud. and brine pit rinses from' mi;d.rg operations via annular. > inject.•ion in perrisi.tted, wells at the Alpine CD2 Drill Site. A's netted below, > AOGCC approved such disposal at the CD1 Drill Site in 1999, based on the > integral relationship of the mud mixing facility and the on-site drilling > operation. > Phillips »c id like to continuing pursuing this request. Si tgz ifiCant. Olean • c *Ut of torike at the _mud mixing facility must occur .in. prea'aration for the. temporary use of oil based mud products at Alpine in. the months. } The availability of annular disposal as an option for tank .rinse fluids and > similar wastes would 41'xe atl faci.litat this process. (Typical,ly, routine > rinses are beneficially. reused•, however, there is a concern about the > potential quantity of fluid that 'could be generated during thin large scale > clean up process.) > Tanks a:. the mud mixing facility idly contain either new and used mud > products. Though rinses in contact with used products may be injected in the permitted class. II disposal. well (CD19 +) rinses :of new products would > potentially be routed to the class'. 1. tlianosal well (wD -02 , where there is • a difficulty managing solids content. The dais i. Well is a critical > li,f.eline for facility infrestr•urtuee, being the disposal location for all > domestic effluent, and it is a priority' to' prevent •any compromise to this > disposal facility. innular disposal °resents a preferred waste management > alternative in this case. • . . • 41111 • • ( > Thank yo4 yery Much for Your aonsideratiOn Of thiS requeet. Please do nOt > heaitate to contact Mei Or My alte Via email or phone at (907} 670-4200 > if you have questions or need additional information. • Shannon Donnelly • > Alpine Field. EnVironmntal CoordinatOr (907) 67 Forwarded byALP Env Ceord/PPCO on. 11/02/01 •250 PM'----- • > ALP Env Coord 08/.31/01 12:45 PM > TO: .LOkpaUndereadMin.state,ak.ua, . Subject: Request to Inject Cement Rineate at CD2 . > Dear Mr. Maunder,- > Injection of cemant inuts and clean-up fluids from mud and brine mixing • operationsat the Alpine mud plant facility into approved annular disposal > operations was granted by the Alaska Oil And Gas Conservation Commission (AGGCC) in €he'rfach 1§09 lettcr from AOVCC to,DOug'Chester of ARCO > Alaska, !c ow Phillip a Alaska, Inc.. {PAI). 1116 approval wean cirai4.6d.t0 > pm specifiCally'for Alpine Drill Site CD1 and authorized Volumes up to • > 35,000 barrels through the annular soace. > PA/ request that thi s. approval be extended to drilling operations at Alpine. ( > Drill Site CD2. Cement )1)ixing Operations for setting surface conduCtOrn he taking placeat the Grind.and Inject facility which is currently > attached to .the drilling rig at CD2, Upon cemPletiOn of the cemnting in > of the conductors, the lines and tank will haute tO be rinsed and the ✓ rinsate disposed of. PA/ request aPprovai to inject this rineate, and other :clean-up from the mud and brine mixing operations, into the annual ✓ space of approved wells lecated at Drill Site CM. : If you have any qUestions please contact me at 670-4200. > TOM Manson. ✓ Alpine Field Environmental Compliance • tomurfaundeLva • • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 woco' I l' ps Telephone 907 - 276 -1215 REER March 22 2010 MAR 2 4 20111 Alaska Oil and Gas Conservation Commission +lask� 4il�GasGq�.COmm +say' 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Anduuf Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3 -124 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3 -124 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3 -124 approximately April 15` 2010. Please find attached form 10 -403AD 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 9 -5/8" x 7" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within'/ mile radius at AOGCC: CD3 -115, CD3 -117, CD3 -118 and CD3 -114. 13. Information regarding remaining wells within '/ mile radius included in sundry package: All wells within '/ mile radius are on file at AOGCC. 14. Copy of previous authorization (CD 1 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 (15.6 ppg) occurred at a lower equivalent mud weight than the casing shoe test (14.6 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 Ryan Robertson at 265 -6318 or Chip Alvord can also be reached by calling 265 -6120. Sincerely, Ryan Robertson Drilling Engineer cc: CD3 -114 Well File Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 • Note to File CRU CD3 -124 (PTD 2100080) April 7, 2010 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3 -124 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the 9 -5/8" x 7" annulus within well CD3 -124. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 - 5/8" surface casing shoe is set in this well at about 3,540'' (- 2,420' true vertical depth subsea, or "TVDSS "), near the base of a 450 -foot thick' mudstone and siltstone 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 silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. 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 less than 150' from the wellbore. Discussion CPAI' s application was reviewed along with well logs from Colville River Unit (CRU) wells CD3 -108, CD3 -113, CD3 -114, CD3 -118, and the Nechelik 1 exploratory well. The mud log from CRU CD3 -114 was also reviewed. An index map is provided in Figure 1, below. The CD3 -124 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3 -124 that extends downward from the 9 -5/8" surface casing shoe, which is set at about 3,540' (- 2,423' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 7,440' ( -3,730 TVDSS). This annulus lies within Sections 5, 6, and 7 of T12N, R5E, Umiat Meridian (see Figure 1). The annulus is located more than 2 miles from the current boundary of the CRU. The section of annulus in CD3 -124 that will most likely accept the injected waste fluids (most likely receptor interval) is a portion of the Seabee formation that extends from about 3657 to 3942' ( -2460' and -2557' TVDSS; see Figure 2, below). This 100 -foot thick interval contains numerous 1- to 2- 1 All depths herein represent measured depths unless otherwise specified. 2 All thicknesses represent true vertical thicknesses unless otherwise specified. Top of cement estimate determined by G. Schwartz, AOGCC, April 7, 2010. • • CD3 -124 April 7, 2010 Note to File Page 2 of 5 foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 15 feet. On the well log from CD3 -124, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9 -5/8" surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9 -5/8" casing shoe consist of mudstone and siltstone (see Figure 3, below). V G7 CD3 -112 \ 06 0320 6021 \ \ \,1 \ I t \ \ \ \ \ ten QCD3.1t5 1 0!+0060 2063 1 Q CD3 -118 '408025021450 � . (124 v _ \ o CD3 -124 D3-1 \ ` 1000&0 CR C 24471 4 QkIQ CRU CD3 -124 2070410 9820 Annulus ~� - ti l7 \ G f a �= ,, ' 8040 { CPFL I � r� "1 --- j „,, k Most Likely Receptor Interval Area of Review (highlighted with red rectangle) (shaded blue) • Surface casing shoe Cement top - — - Figure 1. Index Map (The path of the cross section shown on Figure 3 is highlighted with a red line) The 9 -5/8" surface casing shoe lies near the base of a 450 -foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 50 -foot thick siltstone interval that is also continuous throughout the area. This interval, which lies between about 4183' and 4344' ( -2639' and -2692' TVDSS), and three similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. In vicinity of Drill Site CD3, the base of permafrost occurs at about - 1,250' TVDSS, which is about 1,200' shallower than the top of the likely receptor interval. • • CD3 - 124 April 7, 2010 Note to File Page 3 of 5 Correlation Depth Resis Porosity GR <M[I ResD(RPD) RHOB(NIA) -10 API 240 0.2 OHMM 2001 .65 2.65 and - Sift - Shalel ResM(RPM) ow Poro 0.2 OHMM 200 SP(N!A) ResS(RPS) NPOR -- -100 100 7.2 OHMM 20060 0 <<M D DTCP(N /A) Upper 140 40 Confining Strata ---► 3600 Most Likely 3700 Receptor Interval for 3800 -17501i Disposed Fluids 3900 4000 4100 4200 4300 -271 4400 Lower Confining 4500 non Strata 4600 -2800 4700 4800 7anrl 4900 5000 Figure 2. CD3 -124 Well Log Displaying Affected Intervals Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. CD3 -114 is the only well that was mud logged on Drill Site CD3. In CD3 -114, methane was first encountered at about 1,115' (- 1,050' TVDSS). So, the entire proposed disposal interval likely contains some amount of methane gas. ! 0 CD3 - 124 April 7, 2010 Note to File Page 4 of 5 1811490 2100080 2080250 2070330 2050330 w 501032002000 501032081200 501032057000 501032054400 501032050700 122548 , 4 11411 E 4__ —_ 1598 __ • 4– 74711 , E' SOHIO CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NECHELIK 1 CRU CD3 -124 COLVILLE RN UNIT CD3 118 COLVILLE RIV UNIT CD3 114 COLVILLE RN UNIT CD3 -108 2340 FSL 814 FWL 1127 FEL 4007 FNL 3978 FNL 1010 FEL 3960 FNL 2703 FEL 1349 FSL 818 FEL TWP:12 N- Range :5 E- Sec .18 TWP:12 N- Range - 5 E -Sec. 5 TWP:12 N- Range :5 E - Sec .5 TWP:12 N- Range :5 E- Sec -5 TWP:12 N- Range: 5 E - Sec .5 EN _ ""411 la --"IL – O 1 NOM ,« 1 ti _ Z -I - - _ Upper - _ Confining m 9 -5/8" Casing Shoe Strata e i kely _ �. 1 ' eceptor -C _ , T 1' 1z erval �' - - I Lower _ -_ _ - Confining 7, _ - Strata _I . rf._ I 11 C: _ It - .� 713. 10018 TD•23981 7 13=21450 TW18601 TD•18915 Figure 3. Structural Cross - section from Nechelik 1 TO CRU CD3 -108 The shallowest oil show encountered in well CD3 -114 was observed at 6,050' (- 4,413' TVDSS), about 1850' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of "trace" quality. This instance is judged to represent only small amounts of residual (non- mobile) oil. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial quantities of oil or gas. The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3 -124 that will be affected by the proposed annular disposal operations. There are about 15' of porous sandy siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD3 -124. Neutron and density porosity well logs were run across the proposed disposal interval in nearby well CD3 -108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 125' from the wellbore, as indicated in the chart below. • • CD3 -124 April 7, 2010 Note to File Page 5 of 5 Injected Fluid vs Affected Radial Distance CD3 -124 Wellbore (assumes 15' aggregate injection zone thickness and 28% porosity) 300 250 o 200 E w w • 150 - a cecu t0 100 - o d _ Q • 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3 -124 Annular Disposal Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. I re•.nimend approval of this annular disposal project. Steve Davies Senior Petroleum Geologist • • Note to File CD3 -124 (210- 008...310 -088) Colville River Unit (Fiord pool) 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 with full returns. No problems were reported. Approximately 118 bbls of 10.8 ppg cement was circulated to surface. The net cement remaining in the surface hole was 80% XS of the calculated hole volume. Reciprocated pipe throughout until cement to surface. -- On the initial leak off test completed on 2/11/10, the pressure rises smoothly to 15.6 EMW where a change in slope occurs and continues to rise smoothly to 17.9 EMW with no signs of breakover to this point. Minimal fluid was pumped in at 2.7 barrels . The pressure declined during the observation period to about 15.9 EMW. Two pressure slopes are not uncommon at CRU. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems were reported drilling the intermediate hole. The 7 5/8" casing was run and successfully cemented. Full returns were not mentioned or was pipe reciprocation in the drilling report though a follow -up request from the CPAI engineer stated that the pipe was recip'd and had full returns during the job. The BAT log shows OK cement from the shoe up to 17200' and and above this very good cement. A calculated top of cement for the 2 stage job (isolating the Qannik) puts TOC at 7520' based on 30% excess. - -An injectivity test down 9 -5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 14.6 EMW. The pressure declined with additional pumping to 14.1 EMW. During the observation period, the pressure declined to 13.0 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 ' mite radius of CD3 -124. The nearest surface shoe is CD3 -118, about 462' distant. The well CD3 -117 is about 468' distant. Finally well CD3 -115 is 847' away. 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 ConocoP f lips' re est r the subject well. Guy L. Szh ia Sr, Petroleum Engineer. April 7, 2010 G:\AOGCC\ Common \tommaunder \Well Information\By Subject\Annular Disposal\ 100406_CD3- 124.doc mil.. P7 .4 / ''. C D3-124 3f 0 9 100080 23981 .,- \") it CI A ' Mil 111/4111-1111-, II 1 1 LI 411 il "' - 1 V I 42: 0 r -11 , \ \,. ;k, ... , \ 2010610 9820 \ s, \ 4 3 \ \ i 1 tudl p A*, ,-- % ,,...C,- Ci (-{ • .4;45 ..-- ,,, 6 v , i ,.4q3-411a. 7 '..,),‘,. ..„/ ■-• / ' . IG ' 1 4 „/)„ • .-.4...) rNs' 80 , . _ .1. 7z,,,,(.7./.0 \\, , \ \ ( \ \ _ ___ ., _ \ - _ , N • .,, .....;k:-- . \ \\ 4 51 ._\..5 • • Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 08, 2010 1:29 PM To: 'Anderson, Nina M' Subject: RE: CD3 -124 (PTD 210 -008) Nina, No attachments but.... I think I have the original slides in the PTD. I looked at them again and what you say makes sense. My plots are not in color so can't tell as you describe below. It would be great to have a short paragraph summarizing the AOR wells that might come into question such as Nigliq 1A though. The closest in pool table is very useful but it is not always apparent if close wellbores are above or below the injection zone ND. Maybe a short session with Brig would be good. I can always learn something new !! Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Thursday, April 08, 2010 1:16 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -124 (PTD 210 -008) Guy — For CD3 -124 there are not any wells in the 1 /4 radius within the Fiord pool. The distance between the CD3 -124 well and Nigliq 1A well is far greater than 1320' as the Nigliq 1A well does not penetrate the pool until TD. This well was a slant exploration well and was cemented. Attached are the Sperry plots including the Quarter mile view spider plot. These are submitted with the original permit, although they tend to be in black & white. If you notice on page 3, Brij has created a zoomed in view that highlights the wellbore red when it penetrates the pool. The 4th page has the calculated distance of 2299.9' as the closest approach to CD3 -124 within the pool, which is the toe of the Nigliq 1A well. For all future permits we will include an AOR paragraph that summarizes these 3 slides. We can also submit these in color so that it will be easier to determine the wells that penetrate the pool. Brij also offered to come over and discuss these plots with you. He generates them and can explain how he generates them in further detail. Please let us know if you'd like a brief discussion and if these plots will satisfy your requests. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 575 -3256 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 07, 2010 11:17 AM To: Anderson, Nina M 4/8/2010 • • Page 2 of 3 Subject: RE: CD3 -124 (PTD 210 -008) Nina, I am reviewing the 407 for CD3 -124. On the 1/4 mile plot there is well Nigliq 1A that crosses over CD3 -124. I remember discussing this with you a while back but don't recall many details. Is this well above the Fiord pool so not in the area of review ? ? ?? Don't see it mentioned in the PTD application either. In the future it would be beneficial to document all wells on the spider map ( map view) that are in the 1/4 mile radius in the PTD. An AOR paragraph is really needed stating whether there are any wells in the % mi radius and if they are in zone or not. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Thursday, January 21, 2010 2:50 PM To: Schwartz, Guy L (DOA) Cc: Robertson, Ryan G Subject: RE: CD3-124 (PTD 210 -008) Guy — Yes we have planned to do a BAT sonic log to evaluate the cement quality. This will most likely be run on our clean out BHA which will drill out the intermediate shoe track. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 575 -3256 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 19, 2010 1:55 PM To: Anderson, Nina M Subject: CD3 -124 (PTD 210 -008) Nina, One other item in the procedure that I didn't see was a cement quality log on the 7 5/8" casing . You don't list a BAT sonic in the LWD string or mention a USIT (FASTCAST) on eline. You will need something in order to satisfy the UIC requirements for an injector well. Thanks, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 4/8/2010 • • Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [ Ryan .G.Robertson ©conocophillips.com] Sent: Wednesday, April 07, 2010 3:51 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -124 7 5/8" cement data ( PTD 210 -008) Guy, The 7 -5/8" intermediate cement job on CD3 -124 went very well. The rig was able to reciprocate the casing throughout the cement job, and full returns were achieved during the entire operation. There were no surface or downhole problems to speak of. I will remind the rig supervisors to include this information into the future Weilview reports. Sorry for the late reply. I have been stuck in meetings the entire day until now. Let me know if you need any additional information. Ryan From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 07, 2010 1:10 PM To: Robertson , Ryan G Subject: CD3 -124 7 5/8" cement data ( PTD 210 -008) Ryan, Can you elaborate on the 7 5/8" cement job. The drilling reports don't mention reciprocating or if they got full returns. The BAT log is a little sketchy too... just want some backup info to insure the cement job is good. Guy Schwartz - Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 4/7/2010 RECEIVU STATE OF ALASKA MAR 2 5 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION WE L COMPLETION OR RECOMPLETION REPORT &t S C 10 " la. Well Status: Oil . Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: AlEtlua lle �� ))) 1 20AAC 25.105 20AAC 25.110 Development d Exploratory ❑ GINJ ❑ W 1 INJ ❑ / WAG WDSPL ❑ No. of Completions: _ Service ® Stratigraphic Test ❑ 2. Operator Name: (,JELL Pal eaD 4 44 E ,4 0 , 4 4 0 f r• 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: March 9, 2010 210 - 0080 / 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510 - 0360 February 6, 2010 50 103 - 20612 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1272' FSL, 1127' FEL, Sec. 5, T12N, R5E, UM March 5, 2010 CD3 - 124 Top of Productive Horizon: 8. KB (ft above MSL): 49' RKB 15. Field /Pool(s): 1037' FNL, 693' FEL, Sec. 11, T12N, R4E, UM GL (ft above MSL): 12.5' AMSL Colville River Field Total Depth: 9. Plug Bak_ Depth,(MD + TVD S / 1188' FNL, 1255' FWL, Sec. 2, T12N, R4E, UM --Merl' //0 MD / D Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 387915.6 y 6003770 Zone 4 R. ND / ADL 380077 TPI: x - 372987 y - 6001700 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 369739 y 6006885 Zone 4 2200' MD / 1967' TVD 2560 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1658' MD / 1600' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/Res not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 37' 114' 37' 114' 24" pre - installed 10.75" 45.5# L -80 37' 3540' 37' 2469' 13.5" 574 sx AS Lite, 299 sx Class G 7.625" 29.7# L -80 37' 17888' 37' 7073' 9.875" 705 sx Class G, 299 sx Class G 4.5" 12.6# L -80 17425' 21000' 7063' 7063' 6.75" slotted liner -ro s 2 slat ', 7�" 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5" / 3.5" 129' / 15996' 5787' D / 6580' TVD 17892'- 18733' MD 7073' -7082' TVD 18972' 20157' MD 7078' - 7042' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 20599' 20996' MD 7045' - 7063' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook - up Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD 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. COMPLETION ,1°E. alb NONE p,y. O t Form 10 -407 Revised 12/ pMS MAR 2 6 2010 c CONTINUED ON REVERSE I Submit original only r #,7 ;a a • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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 1658' 1600' needed, and submit detailed test information per 20 AAC 25.071. C30 565' 565' C20 4676' 2854' K -3 7693' 3865' K -2 8206' 4036' Albian 97 12048' 5325' Nanuq 13514' 5817' K -1 16788' 6875' Kuparuk D 16990' 6921' Kuparuk C 17207' 6961' Nuiqsuit 17254' 6970' Nechelik 17833' 7066' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS - Summary of Daily Operations, final directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson @ 265 - 6318 Printed Name the L. Alvord Title: Alaska Drilling Manager Signature 4 ji_. t'� Phone 265 - 6120 Date 312 I' Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 la: 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 12/2009 v-' WNS • CD3 -124 I ConocoPhillips 1 i \, Well Attributes Max Angle & MD TD Al - Sna 4,, i .. Wellbore API/L WI Field Name Well Status 1, Inc! (3 MD (ftKB) Act Btm (ftKB) (..a Mot 501032051200 FIORD NEC IIELIF. PROD 9338 20,34098 23,9810 Comment H25 ; Date Annotation End Date KB -Grd (ft) Rig Release Date III Well Con5g: HORIZONTAL - CO3/24,3/23/2010 81t,56 AM SSSV: 1 PDP Last WO 42 49 3/9/2010 Schematic Actual Annotation Depth (ft KB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason. New Well Pull BaII /Rod, GLV C/0 Imosbor 3/21/2010 HANGER, 31 `,,,. Casing Strings Casing Description String 0 Shin I ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) - String Wt... String ... Skiing Top Thrd CONDUCTOR 24" 16 10.250 37.0 114.0 114.0 6250 H-40 Welded S _ Insulated - Casing Description String 0... 'String ID ... Top Top ((6103) Set Depth (f... Set Depth (ND) ... String Wt... String ... Strinn g Top Thrd `- SURFACE 10 3/4 9.950 36.0 3,540.2 2,468.8 45.50 L80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ...String Wt... String ... String Top Thrd INTERMEDIATE 7 5/8 6.875 33.8 17,888.3 7,070.7 29.70 L - 80 BTC - m Casing Des ption Str ng 0... String ID .Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt..- String -.. String Top Thrd • ''' - FaisiTrT LINER . 41/2 i 3 950 174248 21,000 0 7.0634 I 1260 L-80 SLHT CONDUCTOR 1 Liner Details 24' Insulated, Top Dapih 37 -' 14 (TVD) Top Inc! Nomi... Top (668) (ftKB) ( 3 Item Description Comment ID (In) y'! 17,424.8 6,999.5 8071 Setting Sleeve "HR" Sening Sleeve w/ 10.13' Seal Bore Receptacle 5.750 it 17,437.5 7,001.6 80.65 NIPPLE "RS" Rackoff Seal Nipple 4.850 17,440.0 7,002.0 80.64 HANGER Baker Flexlock DG 5 1/2" Liner Hanger (Shear Pressure 2,000 Psi) 4.900 1 7,449.8 7,003.6' 80.59 XO - Reducing XO - 5 1/2" Hydril 521 Box to 4 1/2" SLHT Pin 3.930 SAFETY - - v` Sri3,. .+€ +t%"t S . 2,200 Tubing Strings � , Tubing Description String 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) . 'String Wt... !String ...IString Top Thrd TUBING 31/2 _992 30.7 15,996.3 6,6479 920 L-80 EUE Com. letion Details To T VD Depth Description N mL.. P (ND) T p Inc' Top (ftKB ( ) (°) Item Comment !D (in) 30.7 30.7 -0.08 HANGER FMC Tubing Hanger 4.500 SURFACE, 128.8 128.8 1.37 X0 - Reducing Crossover -41/2" IBTM Box to 31/2" EUE Pin 2.922 36 - 3,540 - . 2,200.2 1,966.8 54.51 SAFETY VLV CAMCO - TRMA)0-5E SSSV w/ Control Line to Surface; 2.813" X- Profile 2.812 : {. _ 15,787.4 6,579.6 70.53 PACKER Baker 3 1/2" by 7 5/8" Premier Packer 2.870 GAS LIFT, -- _ "- 7 _ -- 6 302 15,835.4 6,595.5 70.57 NIPPLE HES "XN" Nipple Placed 71 ° , w/ 2.75" Minimum ID 2.750 ^; 15,995.8 6,647.8 71.48 WLE:G . - s 1!2" WLEG 4.63" OD 3.00" ID 3.000 Perforations & Slots ' Shol Top (TVD) Btm(ND) Deos Top �t[KBt Blm (ftKB] (ftKB) fftKBJ Zone Date ( - ' Typo Comment e 17,892 18,733 7,071.5 7 3/7/2010 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin i l 18,792 20,158 7,081.7 7,039.6 3/7/2010 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; GAS LIFT, no slots 3' from box/pin 12,856 1._. sl 20,599 20,994 7,044.8 7,063 5 3/7/2010 SLOTS Slots 1 /8x2.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin Notes; General & Safety w ' End Date Annotation 3/21/2010 NOTE VIEW SCHEMA IC w /Alaska Schematic9.0 GAS LIFT, 15,697 PACKER, 15,787 I NIPPLE, 15,835 WLEG, 15,996 - j " TERMEOIATE, Mandrel Details _ - at -�. .: 34- 1],868 Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Stn Top (ftKB) 2 3 3 99.2 02 . 7Q 64 Ca ink ; Model (in) sere TYPe Type (n) (Psi) Run Date Com... 1 1 1 KBMG 1 GAS LIFT GLV BK 0.188 1,882.0 3/14/2010 .0071. 17,892 - 1fl733 1 1 _ 2 12 856.3 5,595.9 70.41 Carrico KBMG 1 GAS LIFT GLV BK 0.188 1,881.0 3/14/2010 I 3 15 697.3 6,549.5 70.46 Carrico KBMG 1 GAS LIFT OV BKO-3 0250 0.0 3/14/2010 SLOTS, 18,792- 20,156 SLOTS, y e, I 1 -- 20,599- 20,994 1 1 . 1 LINER, I I '.. 17,425. 21,000 " - TD, 23,981 • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -124 501032061200 r i y R 10 March, 2010 1 a E4 1 i { i HALLIBURTON Sperry Drilling Services 1 .` • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 © 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 © 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Wellbore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 -124 Database: CPAI EDM Production Project Western North Slope 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 factor Well CD3 - 124 Well Position +N /S 0.00 ft Northing: 6,003,770.97 ft Latitude: 70° 25' 9.257 N +E / - 0.00 ft Fasting: 387,915.68 ft Longitude: 150° 54' 47.125 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft Wellbore CD3 - 124 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) ( (nT) BGGM2009 2/15/2010 21.29 80.78 57,625 Design CD3 - 124 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.79 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) r) 36.79 0.00 0.00 327.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 80.00 543.00 CD3 -124 Gyro (CD3 -124) CB- GYRO -SS Camera based gyro single shot 2/7/2010 12: 579.91 3,502.86 CD3 -124 MWD (R100) (CD3 -124) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 2/7/2010 12: 3,581.56 17,869.81 CD3 -124 MWD (R200) (CD3 -124) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 2/11/2010 1: 17,957.75 23,911.51 CD3 -124 MWD (R300) (CD3 -124) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 2/28/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 36.79 0.00 0.00 36.79 -12.50 0.00 0.00 6,003,770.97 387,915.68 0.00 0.00 UNDEFINED 80.00 0.60 312.14 80.00 30.71 0.15 -0.17 6,003,771.13 387,915.51 1.39 0.22 CB- GYRO -SS (1) 173.00 1.10 317.76 172.99 123.70 1.14 -1.13 6,003,772.13 387,914.57 0.54 1.57 CB- GYRO -SS (1) 265.00 0.53 294.76 264.98 215.69 1.97 -2.11 6,003,772.98 387,913.60 0.70 2.80 CB- GYRO -SS (1) 358.00 0.59 269.49 357.97 308.68 2.15 -2.98 6,003,773.16 387,912.73 0.27 3.42 CB- GYRO -SS (1) 450.00 1.09 264.09 449.96 400.67 2.05 -4.32 6,003,773.09 387,911.39 0.55 4.08 CB- GYRO -SS (1) 543.00 2.38 258.97 542.92 493.63 1.59 -7.10 6,003,772.67 387,908.61 1.40 5.20 CB- GYRO -SS (1) 579.91 3.06 262.84 579.79 530.50 1.32 -8.83 6,003,772.43 387,906.87 1.91 5.92 MWD +IFR -AK- CAZ -SC (2) 672.65 4.65 251.13 672.32 623.03 -0.20 -14.84 6,003,770.99 387,900.84 1.90 7.91 MWD +IFR -AK- CAZ -SC (2) 763.90 5.47 254.67 763.21 713.92 -2.55 -22.54 6,003,768.76 387,893.11 0.96 10.14 MWD +IFR -AK- CAZ -SC (2) 856.30 7.18 253.03 855.05 805.76 -5.40 -32.31 6,003,766.06 387,883.30 1.86 13.07 MWD +IFR -AK- CAZ -SC (2) 3/10/2010 2.0257PM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 @ 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 @ 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Wel lbore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical j MD Inc Azi TVD TVDSS +N/S +E( -W Northing Easting DLS Section (ft) (") (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100) (ft) Survey Tool Name 951.83 11.09 248.96 949.35 900.06 -10.44 -46.60 6,003,761.23 387,868.93 4.15 16.62 MWD +IFR -AK- CAZ -SC (2) 1,047.47 14.00 251.02 1,042.69 993.40 -17.51 -66.13 6,003,754.46 387,849.30 3.08 21.33 MWD +IFR -AK- CAZ -SC (2) 1,142.94 15.28 252.72 1,135.06 1,085.77 -25.00 -89.06 6,003,747.31 387,826.26 1.41 27.54 MWD +IFR -AK- CAZ -SC (2) 1,238.39 19.52 254.26 1,226.12 1,176.83 -33.07 - 116.43 6,003,739.66 387,798.77 4.47 35.68 MWD +IFR -AK- CAZ -SC (2) 1,333.48 23.88 258.36 1,314.46 1,265.17 -41.26 - 150.59 6,003,731.98 387,764.50 4.85 47.41 MWD +IFR -AK- CAZ -SC (2) 1,428.88 27.87 259.27 1,400.28 1,350.99 -49.31 - 191.43 6,003,724.54 387,723.55 4.20 62.90 MWD +IFR -AK- CAZ -SC (2) 1,523.93 31.46 257.60 1,482.86 1,433.57 -58.78 - 237.50 6,003,715.77 387,677.35 3.88 80.05 MWD +IFR -AK- CAZ -SC (2) 1,619.04 35.68 257.51 1,562.09 1,512.80 -70.11 - 288.84 6,003,705.21 387,625.84 4.44 98.51 MWD +IFR -AK- CAZ -SC (2) 1,714.31 39.67 257.19 1,637.48 1,588.19 -82.87 - 345.64 6,003,693.31 387,568.86 4.19 118.75 MWD +IFR -AK- CAZ -SC (2) 1,809.24 43.29 256.20 1,708.59 1,659.30 -97.36 - 406.82 6,003,679.74 387,507.48 3.88 139.92 MWD +IFR -AK- CAZ -SC (2) 1,904.31 44.95 255.83 1,776.83 1,727.54 - 113.35 - 471.04 6,003,664.71 387,443.03 1.77 161.48 MWD +IFR -AK- CAZ -SC (2) 1,998.94 47.82 254.81 1,842.10 1,792.81 - 130.73 - 537.30 6,003,648.34 387,376.52 3.13 183.00 MWD +IFR -AK- CAZ -SC (2) 2,093.81 52.10 253.82 1,903.12 1,853.83 - 150.38 - 607.20 6,003,629.74 387,306.34 4.58 204.59 MWD +IFR -AK- CAZ -SC (2) 2,189.13 54.08 254.39 1,960.37 1,911.08 - 171.24 - 680.50 6,003,609.98 387,232.74 2.13 227.01 MWD +IFR -AK- CAZ -SC (2) 2,284.55 57.84 254.57 2,013.77 1,964.48 - 192.39 - 756.67 6,003,589.98 387,156.27 3.94 250.76 MWD +IFR -AK- CAZ -SC (2) 2,379.47 61.15 254.75 2,061.95 2,012.66 - 214.02 - 835.53 6,003,569.53 387,077.10 3.49 275.57 MWD +IFR -AK- CAZ -SC (2) 2,474.30 64.79 256.30 2,105.04 2,055.75 - 235.12 - 917.31 6,003,549.67 386,995.02 4.11 302.42 MWD +IFR -AK- CAZ -SC (2) 2,569.59 67.87 256.77 2,143.29 2,094.00 - 255.43 - 1,002.17 6,003,530.64 386,909.87 3.26 331.60 MWD +IFR -AK- CAZ -SC (2) 2,663.89 70.77 255.55 2,176.59 2,127.30 - 276.54 - 1,087.82 6,003,510.82 386,823.92 3.30 360.54 MWD +IFR -AK- CAZ -SC (2) 2,759.19 71.59 256.02 2,207.33 2,158.04 - 298.69 - 1,175.27 6,003,489.99 386,736.16 0.98 389.59 MWD +IFR -AK- CAZ -SC (2) 2,854.98 70.38 256.73 2,238.54 2,189.25 - 320.03 - 1,263.28 6,003,469.98 386,647.85 1.44 419.63 MWD +IFR -AK- CAZ -SC (2) 2,949.86 70.28 258.28 2,270.48 2,221.19 - 339.36 - 1,350.50 6,003,451.96 386,560.35 1.54 450.93 MWD +IFR -AK- CAZ -SC (2) 3,044.97 70.71 258.62 2,302.23 2,252.94 - 357.31 - 1,438.34 6,003,435.33 386,472.26 0.56 483.71 MWD +IFR -AK- CAZ -SC (2) 3,140.20 70.13 257.09 2,334.15 2,284.86 - 376.18 - 1,526.05 6,003,417.78 386,384.28 1.63 515.66 MWD +IFR -AK- CAZ -SC (2) 3,235.27 70.49 257.30 2,366.18 2,316.89 - 396.02 - 1,613.33 6,003,399.25 386,296.72 0.43 546.56 MWD +IFR -AK- CAZ -SC (2) 3,330.60 70.27 256.86 2,398.19 2,348.90 - 416.09 - 1,700.86 6,003,380.50 386,208.91 0.49 577.39 MWD +IFR -AK- CAZ -SC (2) 3,426.43 70.28 256.70 2,430.54 2,381.25 - 436.72 - 1,788.67 6,003,361.19 386,120.80 0.16 607.91 MWD +IFR -AK- CAZ -SC (2) 3,502.86 70.48 256.66 2,456.20 2,406.91 - 453.31 - 1,858.73 6,003,345.66 386,050.51 0.27 632.16 MWD +IFR -AK- CAZ -SC (2) 3,581.56 70.14 257.45 2,482.72 2,433.43 - 469.91 - 1,930.94 6,003,330.15 385,978.06 1.04 657.57 MWD +IFR -AK- CAZ -SC (3) 3,670.99 69.98 258.11 2,513.22 2,463.93 - 487.70 - 2,013.11 6,003,313.59 385,895.65 0.72 687.39 MWD +IFR -AK- CAZ -SC (3) 3,771.61 70.21 257.80 2,547.47 2,498.18 - 507.45 - 2,105.63 6,003,295.24 385,802.85 0.37 721.23 MWD +IFR -AK- CAZ -SC (3) 3,867.02 70.00 256.99 2,579.94 2,530.65 - 527.03 - 2,193.18 6,003,276.98 385,715.02 0.83 752.49 MWD +IFR -AK- CAZ -SC (3) 3,959.39 69.83 257.49 2,611.66 2,562.37 - 546.19 - 2,277.79 6,003,259.09 385,630.14 0.54 782.50 MWD +IFR -AK- CAZ -SC (3) 4,052.78 70.20 257.08 2,643.58 2,594.29 - 565.50 - 2,363.41 6,003,241.06 385,544.25 0.57 812.93 MWD +IFR -AK- CAZ -SC (3) 4,150.13 70.46 256.42 2,676.35 2,627.06 - 586.52 - 2,452.64 6,003,221.40 385,454.72 0.69 843.91 MWD +IFR -AK- CAZ -SC (3) 4,245.61 70.58 256.28 2,708.19 2,658.90 - 607.76 - 2,540.11 6,003,201.47 385,366.95 0.19 873.73 MWD +IFR -AK- CAZ -SC (3) 4,342.23 70.12 256.41 2,740.68 2,691.39 - 629.24 - 2,628.53 6,003,181.32 385,278.22 0.49 903.87 MWD +IFR -AK- CAZ -SC (3) 4,431.14 70.06 256.40 2,770.96 2,721.67 - 648.89 - 2,709.78 6,003,162.90 385,196.69 0.07 931.65 MWD +IFR -AK- CAZ -SC (3) 4,532.21 70.11 256.79 2,805.38 2,756.09 - 670.92 - 2,802.22 6,003,142.26 385,103.94 0.37 963.52 MWD +IFR -AK- CAZ -SC (3) 4,626.65 70.09 257.72 2,837.53 2,788.24 - 690.51 - 2,888.83 6,003,123.97 385,017.05 0.93 994.26 MWD +IFR -AK- CAZ -SC (3) 3/10/2010 2:02:57PM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project: Western North Slope TVD Reference: CD3 -124 © 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 @ 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Welibore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) r) r) (ft) (ft) (ft) (f) (ft) (ft) r1100') (ft) Survey Tool Name 4,722.06 70.85 258.48 2,869.43 2,820.14 - 709.05 - 2,976.82 6,003,106.76 384,928.81 1.09 1,026.63 MWD +IFR -AK- CAZ -SC (3) 4,813.04 70.60 258.18 2,899.46 2,850.17 - 726.42 - 3,060.92 6,003,090.65 384,844.46 0.42 1,057.87 MWD +IFR -AK- CAZ -SC (3) 4,911.30 70.43 257.70 2,932.24 2,882.95 - 745.77 - 3,151.51 6,003,072.66 384,753.60 0.49 1,090.98 MWD +IFR -AK- CAZ -SC (3) 5,003.95 70.77 258.16 2,963.01 2,913.72 - 764.05 - 3,236.97 6,003,055.67 384,667.88 0.59 1,122.19 MWD +IFR -AK- CAZ -SC (3) 5,102.53 70.63 257.07 2,995.59 2,946.30 - 784.00 - 3,327.84 6,003,037.09 384,576.73 1.05 1,154.95 MWD +IFR -AK- CAZ -SC (3) 5,196.23 70.46 256.04 3,026.80 2,977.51 - 804.54 - 3,413.77 6,003,017.84 384,490.51 1.05 1,184.52 MWD +IFR -AK- CAZ -SC (3) 5,292.87 70.44 256.62 3,059.14 3,009.85 - 826.07 - 3,502.26 6,002,997.65 384,401.71 0.57 1,214.67 MWD +IFR -AK- CAZ -SC (3) 5,388.01 70.08 256.52 3,091.27 3,041.98 - 846.86 - 3,589.36 6,002,978.16 384,314.32 0.39 1,244.66 MWD +IFR -AK- CAZ -SC (3) 5,482.96 69.93 256.66 3,123.74 3,074.45 - 867.56 - 3,676.15 6,002,958.78 384,227.23 0.21 1,274.58 MWD +IFR -AK- CAZ -SC (3) 5,574.49 70.45 256.83 3,154.76 3,105.47 - 887.30 - 3,759.97 6,002,940.30 384,143.13 0.59 1,303.67 MWD +IFR -AK- CAZ -SC (3) 5,672.66 70.45 257.44 3,187.61 3,138.32 - 907.90 - 3,850.16 6,002,921.06 384,052.65 0.59 1,335.52 MWD +IFR -AK- CAZ -SC (3) 5,768.01 70.66 257.19 3,219.35 3,170.06 - 927.64 - 3,937.87 6,002,902.63 383,964.66 0.33 1,366.73 MWD +IFR -AK- CAZ -SC (3) 5,863.55 70.16 257.22 3,251.39 3,202.10 - 947.58 - 4,025.65 6,002,884.02 383,876.60 0.52 1,397.82 MWD +IFR -AK- CAZ -SC (3) 5,956.14 70.27 255.68 3,282.73 3,233.44 - 967.99 - 4,110.34 6,002,864.88 383,791.62 1.57 1,426.83 MWD +IFR -AK- CAZ -SC (3) 6,054.11 70.18 255.72 3,315.88 3,266.59 - 990.76 -4,199.68 6,002,843.46 383,701.96 0.10 1,456.39 MWD +IFR -AK- CAZ -SC (3) 6,148.09 70.51 255.15 3,347.49 3,298.20 - 1,013.02 - 4,285.34 6,002,822.49 383,615.98 0.67 1,484.37 MWD +IFR -AK- CAZ -SC (3) 6,244.30 70.33 255.34 3,379.73 3,330.44 - 1,036.11 - 4,373.00 6,002,800.73 383,527.99 0.26 1,512.75 MWD +IFR -AK- CAZ -SC (3) 6,336.57 70.55 255.31 3,410.62 3,361.33 - 1,058.13 - 4,457.11 6,002,779.97 383,443.57 0.24 1,540.09 MWD +IFR -AK- CAZ -SC (3) 6,435.07 70.29 255.84 3,443.63 3,394.34 - 1,081.25 - 4,546.98 6,002,758.20 383,353.36 0.57 1,569.65 MWD +IFR -AK- CAZ -SC (3) 6,529.49 70.51 256.78 3,475.30 3,426.01 - 1,102.30 - 4,633.40 6,002,738.45 383,266.64 0.97 1,599.07 MWD +IFR -AK- CAZ -SC (3) 6,625.04 70.38 257.06 3,507.29 3,458.00 - 1,122.68 - 4,721.11 6,002,719.40 383,178.65 0.31 1,629.74 MWD +IFR -AK- CAZ -SC (3) 6,719.27 70.47 257.17 3,538.86 3,489.57 - 1,142.48 - 4,807.66 6,002,700.90 383,091.82 0.15 1,660.28 MWD +IFR -AK- CAZ -SC (3) 6,815.10 70.55 257.89 3,570.83 3,521.54 - 1,161.98 - 4,895.86 6,002,682.72 383,003.34 0.71 1,691.96 MWD +IFR -AK- CAZ -SC (3) 6,908.29 70.60 258.25 3,601.82 3,552.53 - 1,180.15 - 4,981.85 6,002,665.85 382,917.10 0.37 1,723.55 MWD +IFR -AK- CAZ -SC (3) 7,005.46 70.72 258.39 3,634.00 3,584.71 - 1,198.71 - 5,071.64 6,002,648.64 382,827.05 0.18 1,756.89 MWD +IFR -AK- CAZ -SC (3) 7,100.21 70.52 258.44 3,665.44 3,616.15 - 1,216.66 - 5,159.20 6,002,632.01 382,739.24 0.22 1,789.52 MWD +IFR -AK- CAZ -SC (3) 7,195.82 70.44 257.66 3,697.39 3,648.10 - 1,235.32 - 5,247.36 6,002,614.68 382,650.81 0.77 1,821.89 MWD +IFR -AK- CAZ -SC (3) 7,289.18 70.11 257.88 3,728.90 3,679.61 - 1,253.94 - 5,333.25 6,002,597.35 382,564.66 0.42 1,853.05 MWD +IFR -AK- CAZ -SC (3) 7,385.40 70.52 257.81 3,761.31 3,712.02 - 1,273.01 - 5,421.81 6,002,579.61 382,475.83 0.43 1,885.29 MWD +IFR -AK- CAZ -SC (3) 7,479.99 70.17 257.53 3,793.13 3,743.84 - 1,292.03 - 5,508.84 6,002,561.90 382,388.54 0.46 1,916.74 MWD +IFR -AK- CAZ -SC (3) 7,576.37 70.46 257.29 3,825.59 3,776.30 - 1,311.81 - 5,597.40 6,002,543.45 382,299.69 0.38 1,948.38 MWD +IFR -AK- CAZ -SC (3) 7,670.24 70.45 256.90 3,857.00 3,807.71 - 1,331.57 - 5,683.63 6,002,525.00 382,213.19 0.39 1,978.78 MWD +IFR -AK- CAZ -SC (3) 7,766.62 70.31 255.90 3,889.36 3,840.07 - 1,352.92 - 5,771.87 6,002,504.98 382,124.65 0.99 2,008.93 MWD +IFR -AK- CAZ -SC (3) 7,861.29 70.93 256.10 3,920.78 3,871.49 - 1,374.52 - 5,858.52 6,002,484.68 382,037.69 0.68 2,038.01 MWD +IFR -AK- CAZ -SC (3) 7,956.62 70.72 256.22 3,952.09 3,902.80 - 1,396.06 - 5,945.94 6,002,464.46 381,949.95 0.25 2,067.56 MWD +IFR -AK- CAZ -SC (3) 8,049.69 70.17 256.62 3,983.24 3,933.95 - 1,416.65 - 6,031.19 6,002,445.15 381,864.41 0.72 2,096.72 MWD +IFR -AK- CAZ -SC (3) 8,146.64 70.44 257.64 4,015.91 3,966.62 - 1,436.98 - 6,120.18 6,002,426.16 381,775.14 1.03 2,128.13 MWD +IFR -AK- CAZ -SC (3) 8,239.59 70.62 257.56 4,046.89 3,997.60 - 1,455.80 - 6,205.77 6,002,408.63 381,689.29 0.21 2,158.96 MWD +IFR -AK- CAZ -SC (3) 8,335.89 70.53 257.78 4,078.92 4,029.63 - 1,475.20 - 6,294.49 6,002,390.57 381,600.29 0.23 2,191.02 MWD +IFR -AK- CAZ -SC (3) 8,429.69 70.63 257.50 4,110.11 4,060.82 - 1,494.13 - 6,380.90 6,002,372.94 381,513.61 0.30 2,222.20 MWD +IFR -AK- CAZ -SC (3) 3/10/2010 2:02:57PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 @ 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 @ 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Wellbore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N!S +E1-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,526.14 70.51 258.44 4,142.19 4,092.90 - 1,513.09 - 6,469.86 6,002,355.32 381,424.38 0.93 2,254.76 MWD +IFR -AK- CAZ -SC (3) 8,622.35 70.37 258.02 4,174.40 4,125.11 - 1,531.58 - 6,558.61 6,002,338.16 381,335.37 0.44 2,287.58 MWD +IFR -AK- CAZ -SC (3) 8,717.62 70.45 256.85 4,206.35 4,157.06 - 1,551.11 - 6,646.22 6,002,319.95 381,247.49 1.16 2,318.92 MWD +IFR -AK- CAZ -SC (3) 8,812.12 70.57 255.54 4,237.88 4,188.59 - 1,572.37 - 6,732.73 6,002,300.00 381,160.68 1.31 2,348.21 MWD +IFR -AK- CAZ -SC (3) 8,907.51 70.46 256.76 4,269.70 4,220.41 - 1,593.89 - 6,820.04 6,002,279.79 381,073.06 1.21 2,377.71 MWD +IFR -AK- CAZ -SC (3) 9,003.03 70.13 256.63 4,301.90 4,252.61 - 1,614.59 - 6,907.55 6,002,260.41 380,985.26 0.37 2,408.01 MWD +IFR -AK- CAZ -SC (3) 9,097.99 70.20 257.49 4,334.13 4,284.84 - 1,634.59 - 6,994.61 6,002,241.72 380,897.92 0.86 2,438.65 MWD +IFR -AK- CAZ -SC (3) 9,193.29 70.30 257.24 4,366.33 4,317.04 - 1,654.21 - 7,082.13 6,002,223.42 380,810.12 0.27 2,469.87 MWD +IFR -AK- CAZ -SC (3) 9,288.41 70.20 256.95 4,398.47 4,349.18 - 1,674.20 - 7,169.39 6,002,204.74 380,722.57 0.31 2,500.63 MWD +IFR -AK- CAZ -SC (3) 9,382.88 70.19 256.81 4,430.48 4,381.19 - 1,694.38 - 7,255.95 6,002,185.87 380,635.73 0.14 2,530.85 MWD +IFR -AK- CAZ -SC (3) 9,476.92 70.36 257.10 4,462.22 4,412.93 - 1,714.36 - 7,342.19 6,002,167.18 380,549.21 0.34 2,561.06 MWD +IFR -AK- CAZ -SC (3) 9,570.71 70.33 256.98 4,493.77 4,444.48 - 1,734.17 - 7,428.27 6,002,148.67 380,462.85 0.12 2,591.33 MWD +IFR -AK- CAZ -SC (3) 9,666.05 70.45 256.86 4,525.76 4,476.47 - 1,754.49 - 7,515.75 6,002,129.66 380,375.08 0.17 2,621.93 MWD +IFR -AK- CAZ -SC (3) 9,759.66 70.37 257.18 4,557.15 4,507.86 - 1,774.30 - 7,601.69 6,002,111.15 380,288.86 0.33 2,652.12 MWD +IFR -AK- CAZ -SC (3) 9,858.50 70.46 257.41 4,590.28 4,540.99 - 1,794.78 - 7,692.53 6,002,092.04 380,197.73 0.24 2,684.42 MWD +IFR -AK- CAZ -SC (3) 9,951.89 70.53 256.75 4,621.46 4,572.17 - 1,814.47 - 7,778.33 6,002,073.65 380,111.65 0.67 2,714.64 MWD +IFR -AK- CAZ -SC (3) 10,048.67 70.14 257.37 4,654.03 4,604.74 - 1,834.87 - 7,867.15 6,002,054.58 380,022.54 0.73 2,745.90 MWD +IFR -AK- CAZ -SC (3) 10,142.47 70.31 257.09 4,685.77 4,636.48 - 1,854.38 - 7,953.23 6,002,036.36 379,936.18 0.33 2,776.42 MWD +IFR -AK- CAZ -SC (3) 10,239.08 70.40 257.24 4,718.25 4,668.96 - 1,874.60 - 8,041.95 6,002,017.48 379,847.18 0.17 2,807.79 MWD +IFR -AK- CAZ -SC (3) 10,331.14 70.36 257.08 4,749.16 4,699.87 - 1,893.87 - 8,126.49 6,001,999.49 379,762.36 0.17 2,837.67 MWD +IFR -AK- CAZ -SC (3) 10,428.87 70.53 256.54 4,781.87 4,732.58 - 1,914.88 - 8,216.16 6,001,979.82 379,672.40 0.55 2,868.89 MWD +IFR -AK- CAZ -SC (3) 10,520.61 70.66 256.59 4,812.35 4,763.06 - 1,934.99 - 8,300.32 6,001,960.99 379,587.96 0.15 2,897.86 MWD +IFR -AK- CAZ -SC (3) 10,618.95 70.72 256.60 4,844.87 4,795.58 - 1,956.50 - 8,390.60 6,001,940.83 379,497.37 0.06 2,928.99 MWD +IFR -AK- CAZ -SC (3) 10,713.67 70.32 256.13 4,876.46 4,827.17 - 1,977.55 - 8,477.38 6,001,921.09 379,410.29 0.63 2,958.60 MWD +IFR -AK- CAZ -SC (3) 10,809.61 70.33 256.45 4,908.76 4,859.47 - 1,998.96 - 8,565.14 6,001,901.00 379,322.23 0.31 2,988.44 MWD +IFR -AK- CAZ -SC (3) 10,898.73 70.39 256.41 4,938.71 4,889.42 - 2,018.66 - 8,646.73 6,001,882.53 379,240.35 0.08 3,016.36 MWD +IFR -AK- CAZ -SC (3) 11,000.20 70.39 257.24 4,972.77 4,923.48 - 2,040.44 - 8,739.80 6,001,862.15 379,146.98 0.77 3,048.78 MWD +IFR -AK- CAZ -SC (3) 11,094.28 70.66 257.45 5,004.13 4,954.84 - 2,059.87 - 8,826.34 6,001,844.02 379,060.16 0.36 3,079.62 MWD +IFR -AK- CAZ -SC (3) 11,189.69 70.57 256.96 5,035.80 4,986.51 - 2,079.81 - 8,914.11 6,001,825.41 378,972.11 0.49 3,110.70 MWD +IFR -AK- CAZ -SC (3) 11,284.78 70.25 256.73 5,067.69 5,018.40 - 2,100.19 - 9,001.34 6,001,806.34 378,884.59 0.41 3,141.11 MWD +IFR -AK- CAZ -SC (3) 11,380.08 70.46 257.58 5,099.72 5,050.43 - 2,120.15 - 9,088.85 6,001,787.70 378,796.80 0.87 3,172.04 MWD +IFR -AK- CAZ -SC (3) 11,473.21 70.27 257.76 5,131.02 5,081.73 - 2,138.88 - 9,174.54 6,001,770.26 378,710.85 0.27 3,203.00 MWD +IFR -AK- CAZ -SC (3) 11,570.50 70.07 258.09 5,164.02 5,114.73 - 2,158.02 - 9,264.04 6,001,752.46 378,621.08 0.38 3,235.69 MWD +IFR -AK- CAZ -SC (3) 11,664.45 70.23 257.84 5,195.92 5,146.63 - 2,176.45 - 9,350.46 6,001,735.34 378,534.39 0.30 3,267.30 MWD +IFR -AK- CAZ -SC (3) 11,760.75 70.30 257.89 5,228.44 5,179.15 - 2,195.50 - 9,439.08 6,001,717.62 378,445.51 0.09 3,299.59 MWD +IFR -AK- CAZ -SC (3) 11,853.17 70.40 256.95 5,259.52 5,210.23 - 2,214.46 - 9,524.03 6,001,699.94 378,360.29 0.96 3,329.96 MWD +IFR -AK- CAZ -SC (3) 11,951.34 70.04 256.27 5,292.74 5,243.45 - 2,235.85 - 9,613.89 6,001,679.90 378,270.12 0.75 3,360.96 MWD +IFR -AK- CAZ -SC (3) 12,045.59 70.40 256.41 5,324.64 5,275.35 - 2,256.80 - 9,700.08 6,001,660.25 378,183.65 0.41 3,390.33 MWD +IFR -AK- CAZ -SC (3) 12,141.20 70.66 256.39 5,356.51 5,307.22 - 2,277.99 - 9,787.69 6,001,640.38 378,095.73 0.27 3,420.27 MWD +IFR -AK- CAZ -SC (3) 12,236.09 70.53 256.34 5,388.03 5,338.74 - 2,299.09 - 9,874.67 6,001,620.59 378,008.45 0.15 3,449.95 MWD +IFR -AK- CAZ -SC (3) 3/10/2010 2:02:57PM Page 5 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 @ 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 @ 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Wellbore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD 7VDSS +NI-S +V -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °11001 (ft) Survey Tool Name 12,331.30 70.57 257.23 5,419.74 5,370.45 - 2,319.61 - 9,962.07 6,001,601.38 377,920.76 0.88 3,480.34 MWD +IFR -AK- CAZ -SC (3) 12,424.96 70.46 257.51 5,450.98 5,401.69 - 2,338.92 - 10,048.23 6,001,583.37 377,834.33 0.31 3,511.07 MWD +IFR -AK- CAZ -SC (3) 12,521.96 70.25 257.55 5,483.59 5,434.30 - 2,358.65 - 10,137.42 6,001,564.99 377,744.86 0.22 3,543.11 MWD +IFR -AK- CAZ -SC (3) 12,616.89 70.19 258.73 5,515.71 5,466.42 - 2,377.01 - 10,224.84 6,001,547.95 377,657.18 1.17 3,575.32 MWD +IFR -AK- CAZ -SC (3) 12,712.11 70.52 257.95 5,547.73 5,498.44 - 2,395.13 - 10,312.67 6,001,531.15 377,569.10 0.85 3,607.96 MWD +IFR -AK- CAZ -SC (3) 12,805.14 70.51 257.57 5,578.76 5,529.47 - 2,413.72 - 10,398.38 6,001,513.84 377,483.13 0.39 3,639.04 MWD +IFR -AK- CAZ -SC (3) 12,898.30 70.32 256.96 5,609.99 5,560.70 - 2,433.07 - 10,483.99 6,001,495.78 377,397.24 0.65 3,669.44 MWD +IFR -AK- CAZ -SC (3) 12,989.21 70.14 256.62 5,640.74 5,591.45 - 2,452.62 - 10,567.28 6,001,477.49 377,313.68 0.40 3,698.41 MWD +IFR -AK- CAZ -SC (3) 13,082.16 70.12 254.98 5,672.33 5,623.04 - 2,474.06 - 10,652.02 6,001,457.32 377,228.63 1.66 3,726.58 MWD +IFR -AK- CAZ -SC (3) 13,174.66 70.66 255.62 5,703.38 5,654.09 - 2,496.17 - 10,736.30 6,001,436.48 377,144.03 0.87 3,753.94 MWD +IFR -AK- CAZ -SC (3) 13,268.44 70.67 255.47 5,734.43 5,685.14 - 2,518.26 - 10,821.99 6,001,415.68 377,058.03 0.15 3,782.08 MWD +IFR -AK- CAZ -SC (3) 13,360.30 70.12 255.55 5,765.25 5,715.96 - 2,539.92 - 10,905.77 6,001,395.29 376,973.94 0.60 3,809.56 MWD +IFR -AK- CAZ -SC (3) 13,455.64 70.20 256.09 5,797.61 5,748.32 - 2,561.88 - 10,992.72 6,001,374.63 376,886.68 0.54 3,838.49 MWD +IFR -AK- CAZ -SC (3) 13,549.05 70.07 256.02 5,829.35 5,780.06 - 2,583.06 - 11,077.98 6,001,354.75 376,801.11 0.16 3,867.17 MWD +IFR -AK- CAZ -SC (3) 13,640.51 70.71 256.72 5,860.04 5,810.75 - 2,603.36 - 11,161.71 6,001,335.71 376,717.10 1.00 3,895.74 MWD +IFR -AK- CAZ -SC (3) 13,734.90 70.56 257.27 5,891.34 5,842.05 - 2,623.40 - 11,248.48 6,001,316.97 376,630.05 0.57 3,926.19 MWD +IFR -AK- CAZ -SC (3) 13,827.65 70.59 257.01 5,922.19 5,872.90 - 2,642.87 - 11,333.75 6,001,298.79 376,544.50 0.27 3,956.31 MWD +IFR -AK- CAZ -SC (3) 13,919.81 70.58 257.09 5,952.82 5,903.53 - 2,662.34 - 11,418.46 6,001,280.59 376,459.51 0.08 3,986.11 MWD +IFR -AK- CAZ -SC (3) 14,013.59 70.20 257.36 5,984.30 5,935.01 - 2,681.88 - 11,504.61 6,001,262.35 376,373.08 0.49 4,016.65 MWD +IFR -AK- CAZ -SC (3) 14,104.77 70.59 258.30 6,014.89 5,965.60 - 2,699.98 - 11,588.58 6,001,245.51 376,288.87 1.06 4,047.19 MWD +IFR -AK- CAZ -SC (3) 14,197.64 70.39 258.19 6,045.91 5,996.62 - 2,717.82 - 11,674.28 6,001,228.96 376,202.91 0.24 4,078.91 MWD +IFR -AK- CAZ -SC (3) 14,287.96 70.12 257.16 6,076.42 6,027.13 - 2,735.96 - 11,757.33 6,001,212.07 376,119.61 1.11 4,108.93 MWD +IFR -AK- CAZ -SC (3) 14,381.84 70.52 257.22 6,108.04 6,058.75 - 2,755.56 - 11,843.52 6,001,193.77 376,033.13 0.43 4,139.44 MWD +IFR -AK- CAZ -SC (3) 14,474.59 70.45 257.60 6,139.02 6,089.73 - 2,774.62 - 11,928.84 6,001,176.00 375,947.55 0.39 4,169.92 MWD +IFR -AK- CAZ -SC (3) 14,568.41 70.25 257.79 6,170.57 6,121.28 - 2,793.45 - 12,015.17 6,001,158.47 375,860.95 0.29 4,201.15 MWD +IFR -AK- CAZ -SC (3) 14,661.20 70.37 257.31 6,201.83 6,152.54 - 2,812.28 - 12,100.48 6,001,140.92 375,775.38 0.50 4,231.81 MWD +IFR -AK- CAZ -SC (3) 14,755.33 70.26 256.87 6,233.54 6,184.25 - 2,832.08 - 12,186.87 6,001,122.42 375,688.71 0.46 4,262.26 MWD +IFR -AK- CAZ -SC (3) 14,846.32 70.20 256.81 6,264.32 6,215.03 - 2,851.58 - 12,270.25 6,001,104.18 375,605.06 0.09 4,291.32 MWD +IFR -AK- CAZ -SC (3) 14,941.41 70.39 256.21 6,296.38 6,247.09 - 2,872.46 - 12,357.30 6,001,084.61 375,517.71 0.63 4,321.22 MWD +IFR -AK- CAZ -SC (3) 15,034.72 70.17 256.98 6,327.86 6,278.57 - 2,892.83 - 12,442.74 6,001,065.53 375,431.98 0.81 4,350.67 MWD +IFR -AK- CAZ -SC (3) 15,127.95 70.52 257.01 6,359.22 6,309.93 - 2,912.58 - 12,528.29 6,001,047.06 375,346.15 0.38 4,380.70 MWD +IFR -AK- CAZ -SC (3) 15,218.52 70.05 257.65 6,389.78 6,340.49 - 2,931.28 - 12,611.47 6,001,029.61 375,262.70 0.84 4,410.32 MWD +IFR -AK- CAZ -SC (3) 15,311.86 69.86 257.07 6,421.77 6,372.48 - 2,950.47 - 12,697.03 6,001,011.71 375,176.87 0.62 4,440.82 MWD +IFR -AK- CAZ -SC (3) 15,398.72 70.44 257.45 6,451.26 6,401.97 - 2,968.49 - 12,776.72 6,000,994.89 375,096.93 0.78 4,469.12 MWD +IFR -AK- CAZ -SC (3) 15,493.23 70.32 260.29 6,483.00 6,433.71 - 2,985.67 - 12,864.06 6,000,979.03 375,009.35 2.83 4,502.27 MWD +IFR -AK- CAZ -SC (3) 15,587.13 70.78 262.59 6,514.27 6,464.98 - 2,998.85 - 12,951.60 6,000,967.17 374,921.62 2.36 4,538.90 MWD +IFR -AK- CAZ -SC (3) 15,680.74 71.37 264.64 6,544.64 6,495.35 - 3,008.69 - 13,039.60 6,000,958.65 374,833.50 2.17 4,578.57 MWD +IFR -AK- CAZ -SC (3) 15,772.31 70.52 266.95 6,574.54 6,525.25 - 3,015.04 - 13,125.91 6,000,953.59 374,747.11 2.56 4,620.26 MWD +IFR -AK- CAZ -SC (3) 15,865.72 70.59 269.81 6,605.64 6,556.35 - 3,017.53 - 13,213.95 6,000,952.43 374,659.05 2.89 4,666.12 MWD +IFR -AK- CAZ -SC (3) 15,957.60 71.29 271.48 6,635.64 6,586.35 - 3,016.55 - 13,300.78 6,000,954.71 374,572.25 1.88 4,714.23 MWD +IFR -AK- CAZ -SC (3) 3/10/2010 2:02:57PM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 © 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 © 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Wellbore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +N/-S +EI -W Northing Easting DLS Section (ft) () (°) (f) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 16,049.91 71.76 272.56 6,664.90 6,615.61 - 3,013.46 - 13,388.27 6,000,959.11 374,484.82 1.22 4,764.47 MWD +IFR -AK- CAZ -SC (3) 16,141.54 72.09 274.03 6,693.33 6,644.04 - 3,008.46 - 13,475.24 6,000,965.42 374,397.95 1.57 4,816.04 MWD +IFR -AK- CAZ -SC (3) 16,234.86 72.02 275.00 6,722.08 6,672.79 - 3,001.47 - 13,563.74 6,000,973.74 374,309.57 0.99 4,870.10 MWD +IFR -AK- CAZ -SC (3) ' 16,328.86 72.34 276.95 6,750.85 6,701.56 - 2,992.15 - 13,652.74 6,000,984.39 374,220.73 2.00 4,926.38 MWD +IFR -AK- CAZ -SC (3) 16,419.77 73.44 279.71 6,777.60 6,728.31 - 2,979.56 - 13,738.70 6,000,998.27 374,134.98 3.14 4,983.76 MWD +IFR -AK- CAZ -SC (3) 16,515.40 74.08 281.62 6,804.35 6,755.06 - 2,962.57 - 13,828.92 6,001,016.61 374,045.03 2.03 5,047.15 MWD +IFR -AK- CAZ -SC (3) 16,607.67 74.60 284.11 6,829.26 6,779.97 - 2,942.78 - 13,915.52 6,001,037.69 373,958.73 2.66 5,110.91 MWD +IFR -AK- CAZ -SC (3) 16,701.46 75.50 286.26 6,853.46 6,804.17 - 2,919.05 - 14,002.97 6,001,062.74 373,871.66 2.41 5,178.44 MWD +IFR -AK- CAZ -SC (3) 16,794.49 75.72 288.73 6,876.58 6,827.29 - 2,891.96 - 14,088.90 6,001,091.11 373,786.15 2.58 5,247.97 MWD +IFR -AK- CAZ -SC (3) 16,888.56 76.61 291.68 6,899.08 6,849.79 - 2,860.41 - 14,174.61 6,001,123.94 373,700.94 3.19 5,321.10 MWD +IFR -AK- CAZ -SC (3) 16,980.96 78.21 294.90 6,919.22 6,869.93 - 2,824.76 - 14,257.42 6,001,160.83 373,618.68 3.82 5,396.11 MWD +IFR -AK- CAZ -SC (3) 17,075.57 79.34 298.07 6,937.64 6,888.35 - 2,783.37 - 14,340.47 6,001,203.45 373,536.27 3.50 5,476.05 MWD +IFR -AK- CAZ -SC (3) 17,169.16 79.71 301.41 6,954.66 6,905.37 - 2,737.72 - 14,420.36 6,001,250.29 373,457.07 3.53 5,557.84 MWD +IFR -AK- CAZ -SC (3) 17,263.06 79.90 304.59 6,971.29 6,922.00 - 2,687.40 - 14,497.86 6,001,301.77 373,380.35 3.34 5,642.26 MWD +IFR -AK- CAZ -SC (3) 17,356.60 79.84 308.28 6,987.75 6,938.46 - 2,632.72 - 14,571.93 6,001,357.55 373,307.11 3.88 5,728.46 MWD +IFR -AK- CAZ -SC (3) 17,449.90 80.59 311.53 7,003.61 6,954.32 - 2,573.74 - 14,642.45 6,001,417.57 373,237.50 3.53 5,816.33 MWD +IFR -AK- CAZ -SC (3) 17,543.20 80.16 315.29 7,019.21 6,969.92 - 2,510.54 - 14,709.26 6,001,481.77 373,171.65 4.00 5,905.72 MWD +IFR -AK- CAZ -SC (3) 17,637.03 79.89 317.68 7,035.47 6,986.18 - 2,443.53 - 14,772.89 6,001,549.72 373,109.04 2.53 5,996.57 MWD +IFR -AK- CAZ -SC (3) 17,730.18 80.90 320.33 7,051.01 7,001.72 - 2,374.21 - 14,833.13 6,001,619.92 373,049.85 3.01 6,087.52 MWD +IFR -AK- CAZ -SC (3) 17,822.76 82.21 321.92 7,064.61 7,015.32 - 2,302.92 - 14,890.60 6,001,692.06 372,993.46 2.21 6,178.61 MWD +IFR -AK- CAZ -SC (3) 17,869.81 82.65 322.55 7,070.81 7,021.52 - 2,266.05 - 14,919.16 6,001,729.36 372,965.46 1.62 6,225.08 MWD +IFR -AK- CAZ -SC (3) 17,957.75 83.68 320.38 7,081.27 7,031.98 - 2,197.76 - 14,973.55 6,001,798.45 372,912.10 2.72 6,311.99 MWD +IFR -AK- CAZ -SC (4) 18,051.18 86.95 321.53 7,088.90 7,039.61 - 2,125.45 - 15,032.20 6,001,871.63 372,854.55 3.71 6,404.57 MWD +IFR -AK- CAZ -SC (4) 18,147.96 88.69 321.95 7,092.59 7,043.30 - 2,049.51 - 15,092.08 6,001,948.45 372,795.82 1.85 6,500.87 MWD +IFR -AK- CAZ -SC (4) 18,245.17 90.23 322.78 7,093.50 7,044.21 - 1,972.54 - 15,151.44 6,002,026.30 372,737.63 1.80 6,597.75 MWD +IFR -AK- CAZ -SC (4) 18,340.52 92.20 322.48 7,091.48 7,042.19 - 1,896.78 - 15,209.30 6,002,102.91 372,680.92 2.09 6,692.80 MWD +IFR -AK- CAZ -SC (4) 18,436.33 92.15 322.49 7,087.84 7,038.55 - 1,820.84 - 15,267.60 6,002,179.71 372,623.77 0.05 6,788.25 MWD +IFR -AK- CAZ -SC (4) 18,531.45 91.09 320.94 7,085.15 7,035.86 - 1,746.21 - 15,326.51 6,002,255.21 372,566.00 1.97 6,882.92 MWD +IFR -AK- CAZ -SC (4) 18,626.11 90.85 319.33 7,083.55 7,034.26 - 1,673.57 - 15,387.17 6,002,328.75 372,506.43 1.72 6,976.88 MWD +IFR -AK- CAZ -SC (4) 18,721.20 90.54 318.17 7,082.40 7,033.11 - 1,602.08 - 15,449.86 6,002,401.16 372,444.83 1.26 7,070.98 MWD +IFR -AK- CAZ -SC (4) 18,816.73 90.54 318.97 7,081.50 7,032.21 - 1,530.46 - 15,513.07 6,002,473.72 372,382.71 0.84 7,165.47 MWD +IFR -AK- CAZ -SC (4) 18,912.30 91.22 320.85 7,080.03 7,030.74 - 1,457.36 - 15,574.61 6,002,547.73 372,322.28 2.09 7,260.30 MWD +IFR -AK- CAZ -SC (4) 19,007.25 91.77 321.83 7,077.55 7,028.26 - 1,383.24 - 15,633.90 6,002,622.72 372,264.11 1.18 7,354.75 MWD +IFR -AK- CAZ -SC (4) 19,102.87 92.02 321.96 7,074.39 7,025.10 - 1,308.04 - 15,692.88 6,002,698.79 372,206.28 0.29 7,449.94 MWD +IFR -AK- CAZ -SC (4) 19,198.74 91.47 321.69 7,071.47 7,022.18 - 1,232.71 - 15,752.10 6,002,775.00 372,148.19 0.64 7,545.37 MWD +IFR -AK- CAZ -SC (4) 19,296.52 92.33 318.81 7,068.23 7,018.94 - 1,157.58 - 15,814.59 6,002,851.05 372,086.85 3.07 7,642.41 MWD +IFR -AK- CAZ -SC (4) 19,388.45 91.96 319.69 7,064.79 7,015.50 - 1,087.99 - 15,874.55 6,002,921.53 372,027.94 1.04 7,733.44 MWD +IFR -AK- CAZ -SC (4) 19,483.65 92.82 320.36 7,060.82 7,011.53 - 1,015.10 - 15,935.66 6,002,995.32 371,967.94 1.14 7,827.85 MWD +IFR -AK- CAZ -SC (4) 19,579.68 92.21 320.21 7,056.60 7,007.31 - 941.30 - 15,996.96 6,003,070.03 371,907.76 0.65 7,923.13 MWD +IFR -AK- CAZ -SC (4) 19,673.48 92.33 320.75 7,052.89 7,003.60 - 869.00 - 16,056.60 6,003,143.21 371,849.22 0.59 8,016.25 MWD +IFR -AK- CAZ -SC (4) 3/10/2010 2:02:57PM Page 7 COMPASS 2003.16 Build 69 . • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 @ 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 © 49.29ft ( Doyon 19) Well: CD3 - 124 North Reference: True Wel!bore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +Ef -W Northing Easting DLS Section (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/1001 (ft) Survey Tool Name 19,768.61 91.47 323.95 7,049.73 7,000.44 - 793.73 - 16,114.67 6,003,219.33 371,792.29 3.48 8,111.00 MWD +IFR -AK- CAZ -SC (4) 19,860.25 91.16 321.26 7,047.63 6,998.34 - 720.95 - 16,170.30 6,003,292.93 371,737.76 2.95 8,202.34 MWD +IFR -AK- CAZ -SC (4) 19,959.81 90.85 320.05 7,045.88 6,996.59 - 643.97 - 16,233.41 6,003,370.85 371,675.82 1.25 8,301.27 MWD +IFR -AK- CAZ -SC (4) 20,055.21 91.46 322.53 7,043.96 6,994.67 - 569.55 - 16,293.06 6,003,446.15 371,617.30 2.68 8,396.17 MWD +IFR -AK- CAZ -SC (4) 20,150.50 90.35 321.47 7,042.46 6,993.17 - 494.47 - 16,351.71 6,003,522.09 371,559.79 1.61 8,491.08 MWD +IFR -AK- CAZ -SC (4) 20,244.61 90.97 325.75 7,041.37 6,992.08 - 418.74 - 16,407.53 6,003,598.65 371,505.12 4.60 8,585.00 MWD +IFR -AK- CAZ -SC (4) 20,340.99 93.38 329.38 7,037.71 6,988.42 - 337.47 - 16,459.18 6,003,680.67 371,454.70 4.52 8,681.28 MWD +IFR -AK- CAZ -SC (4) 20,429.82 89.06 327.30 7,035.82 6,986.53 - 261.90 - 16,505.78 6,003,756.93 371,409.24 5.40 8,770.04 MWD +IFR -AK- CAZ -SC (4) 20,529.80 86.09 324.09 7,040.05 6,990.76 - 179.41 - 16,562.06 6,003,840.25 371,354.21 4.37 8,869.88 MWD +IFR -AK- CAZ -SC (4) 20,625.13 85.97 324.84 7,046.65 6,997.36 - 102.02 - 16,617.33 6,003,918.46 371,300.11 0.79 8,964.89 MWD +IFR -AK- CAZ -SC (4) 20,723.06 86.40 326.95 7,053.17 7,003.88 -21.12 - 16,672.12 6,004,000.17 371,246.55 2.19 9,062.58 MWD +IFR -AK- CAZ -SC (4) 20,816.91 87.02 329.08 7,058.56 7,009.27 58.35 -16,721.74 6,004,080.36 371,198.13 2.36 9,156.25 MWD+IFR-AK-CAZ-SC (4) 20,912.62 88.13 331.00 7,062.61 7,013.32 141.19 - 16,769.50 6,004,163.90 371,151.63 2.32 9,251.74 MWD +IFR -AK- CAZ -SC (4) 21 008.78 91.09 333.91 7,063.26 7,013.97 226.43 -16,813.95 6,004,249.79 371 108.46 4.32 9,347.44 MWD +IFR -AK- CAZ -SC (4) 21,102.82 91.28 332.10 7,061.32 7,012.03 310.20 - 16,856.63 6,004,334.19 371,067.05 1.93 9,440.94 MWD +IFR -AK- CAZ -SC (4) 21,198.20 90.91 332.43 7,059.49 7,010.20 394.61 - 16,901.01 6,004,419.25 371,023.95 0.52 9,535.90 MWD +IFR -AK- CAZ -SC (4) 21,293.96 91.40 333.21 7,057.56 7,008.27 479.78 - 16,944.74 6,004,505.05 370,981.50 0.96 9,631.14 MWD +IFR -AK- CAZ -SC (4) 21,389.63 92.21 333.99 7,054.55 7,005.26 565.43 - 16,987.26 6,004,591.32 370,940.28 1.18 9,726.13 MWD +IFR -AK- CAZ -SC (4) 21,486.79 93.32 334.21 7,049.86 7,000.57 652.73 - 17,029.65 6,004,679.24 370,899.21 1.16 9,822.43 MWD +IFR -AK- CAZ -SC (4) 21,579.50 92.70 333.33 7,044.99 6,995.70 735.77 - 17,070.57 6,004,762.89 370,859.55 1.16 9,914.37 MWD +IFR -AK- CAZ -SC (4) 21,677.43 90.97 331.12 7,041.86 6,992.57 822.37 - 17,116.17 6,004,850.15 370,815.25 2.86 10,011.83 MWD +IFR -AK- CAZ -SC (4) 21,773.63 90.29 330.94 7,040.80 6,991.51 906.52 - 17,162.76 6,004,934.99 370,769.93 0.73 10,107.79 MWD +IFR -AK- CAZ -SC (4) 21,868.61 92.14 331.09 7,038.79 6,989.50 989.58 - 17,208.78 6,005,018.72 370,725.17 1.95 10,202.51 MWD +IFR -AK- CAZ -SC (4) 21,963.61 92.02 331.14 7,035.34 6,986.05 1,072.71 - 17,254.64 6,005,102.52 370,680.57 0.14 10,297.20 MWD +IFR -AK- CAZ -SC (4) 22,059.53 92.08 330.39 7,031.91 6,982.62 1,156.36 - 17,301.45 6,005,186.85 370,635.02 0.78 10,392.85 MWD +IFR -AK- CAZ -SC (4) 22,155.84 92.21 330.51 7,028.30 6,979.01 1,240.08 - 17,348.92 6,005,271.27 370,588.82 0.18 10,488.92 MWD +IFR -AK- CAZ -SC (4) 22,248.67 92.27 331.12 7,024.67 6,975.38 1,321.07 - 17,394.15 6,005,352.92 370,544.81 0.66 10,581.47 MWD +IFR -AK- CAZ -SC (4) 22,345.76 89.98 331.78 7,022.77 6,973.48 1,406.33 - 17,440.54 6,005,438.86 370,499.71 2.45 10,678.24 MWD +IFR -AK- CAZ -SC (4) 22,438.53 89.74 332.43 7,022.99 6,973.70 1,488.32 - 17,483.94 6,005,521.49 370,457.55 0.75 10,770.65 MWD +IFR -AK- CAZ -SC (4) 22,536.33 90.41 332.69 7,022.87 6,973.58 1,575.11 - 17,529.01 6,005,608.94 370,413.79 0.73 10,867.98 MWD +IFR -AK- CAZ -SC (4) 22,631.36 90.42 332.70 7,022.18 6,972.89 1,659.55 - 17,572.60 6,005,694.02 370,371.48 0.01 10,962.54 MWD +IFR -AK- CAZ -SC (4) 22,726.64 90.41 331.55 7,021.49 6,972.20 1,743.77 - 17,617.15 6,005,778.89 370,328.21 1.21 11,057.44 MWD +IFR -AK- CAZ -SC (4) 22,822.48 89.86 329.83 7,021.26 6,971.97 1,827.34 - 17,664.06 6,005,863.15 370,282.56 1.88 11,153.07 MWD +IFR -AK- CAZ -SC (4) 22,917.78 90.72 333.08 7,020.78 6,971.49 1,911.04 - 17,709.60 6,005,947.52 370,238.29 3.53 11,248.07 MWD +IFR -AK- CAZ -SC (4) 23,013.36 90.29 333.91 7,019.94 6,970.65 1,996.57 - 17,752.25 6,006,033.67 370,196.93 0.98 11,343.03 MWD +IFR -AK- CAZ -SC (4) 23,108.55 90.11 333.86 7,019.60 6,970.31 2,082.04 - 17,794.15 6,006,119.75 370,156.32 0.20 11,437.54 MWD +IFR -AK- CAZ -SC (4) 23,204.41 89.49 333.12 7,019.94 6,970.65 2,167.82 - 17,836.93 6,006,206.16 370,114.83 1.01 11,532.78 MWD +IFR -AK- CAZ -SC (4) 23,297.38 92.14 331.17 7,018.62 6,969.33 2,250.00 - 17,880.36 6,006,288.97 370,072.64 3.54 11,625.35 MWD +IFR -AK- CAZ -SC (4) 23,393.42 91.53 329.76 7,015.54 6,966.25 2,333.52 - 17,927.68 6,006,373.18 370,026.59 1.60 11,721.17 MWD +IFR -AK- CAZ -SC (4) 23,490.43 93.26 331.15 7,011.49 6,962.20 2,417.83 - 17,975.47 6,006,458.20 369,980.07 2.29 11,817.91 MWD +IFR -AK- CAZ -SC (4) 3/10/2010 2:02:57PM Page 8 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -124 Project Western North Slope TVD Reference: CD3 -124 @ 49.29ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -124 @ 49.29ft (Doyon 19) Well: CD3 - 124 North Reference: True Wellbore: CD3 - 124 Survey Calculation Method: Minimum Curvature Design: CD3 - 124 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az' TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) ( °1100 (ft) Survey Tool Name 23,586.20 91.71 329.88 7,007.33 6,958.04 2,501.12 - 18,022.56 6,006,542.17 369,934.24 2.09 11,913.40 MWD +IFR- AK- CAZ -SC (4) 23,681.69 91.47 329.69 7,004.69 6,955.40 2,583.60 - 18,070.60 6,006,625.36 369,887.45 0.32 12,008.74 MWD +IFR- AK- CAZ -SC (4) 23,776.87 90.29 328.74 7,003.22 6,953.93 2,665.36 - 18,119.31 6,006,707.83 369,839.98 1.59 12,103.84 MWD +IFR- AK- CAZ -SC (4) 23,871.81 90.66 329.64 7,002.44 6,953.15 2,746.90 - 18,167.93 6,006,790.08 369,792.59 1.02 12,198.71 MWD +IFR- AK- CAZ -SC (4) 23,911.51 89.43 329.83 7,002.41 6,953.12 2,781.18 - 18,187.94 6,006,824.67 369,773.10 3.13 12,238.36 MWD +IFR- AK- CAZ -SC (4) 23,981.00 89.43 329.83 7,003.10 6,953.81 2,841.26 - 18,222.86 6,006,885.25 369,739.09 0.00 12,307.76 PROJECTED to TD 3/10/2010 2 :02 :57PM Page 9 COMPASS 2003.16 Build 69 • • • ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: CD3 - 124 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 2/6/2010 8:00:00 AM Rig Release: 3/9/2010 9:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/05/2010 24 hr Summary Disconnect Service Lines - Prep to Move U CD3 -124 23:00 00:00 1.00 0 0 MIRU MOVE DMOB P Disconnect Service Lines - Prep Rig for Move t/ CD3 -124 02/06/2010 Move Rig f/ CD3 -122 to CD3 -124 - Connect High Line Power, Connect Service Lines, N/U Riser and Take on Spud Mud - Hold Pre -Spud Meeting w/ Rig Team - M/U BHA #1 - ,Drill 13 1/2" Hole w/ Motor f/ 114' - 684' MD (SS Gyros Taken U 628' MD) 00:00 08:00 8.00 0 0 MIRU MOVE MOB P Move Pits /Motor Complexes - Skid Sub Floor - Move Rig f/ CD3 -122 to CD3 -124 - Spot & Level Rig - Skid Floor & Move Pits /Motor Complexes into Position - Hook Up Service Lines - N/U Riser and Connect High Line Power - Rig Accepted @ 0800 08:00 10:45 2.75 0 0 MIRU DRILL RURD P Install Mouse Hole - Take On Spud Mud - Move Smaller BHA Components to the Rig Floor 10:45 11:00 0.25 0 0 MIRU DRILL SFTY P PJSM on Picking Up BHA #1 11:00 12:45 1.75 0 0 SURFA( DRILL PULD P P/U BHA #1 as Follows: Mud Motor, Bit, IBS, EM Collar, INdex Sub, Antenna! Sub, NM Float Sub, NM UBHO - Orient UBHO - M/U 2 Jts NMFDC's and Jars 12:45 13:15 0.50 0 0 SURFA( DRILL SFTY P Hold Pre -Spud Safety Meeting w/ Rig Team 13:15 14:00 0.75 0 0 SURFA( DRILL PRTS P Fill the Stack and Check for Leaks - Pressure Test Surface Lines U 3800 Psi - Hand E -Line Sheave 14:00 00:00 10.00 0 684 SURFA( DRILL DDRL P Drill 13 1/2" Hole w/ 1.5° Bent Motor f/ 114' - 684' MD - Take Eline Gyros Every Stand U 628' MD P/U 105, S/O 100, Rot 105 Torque On /Off 6,000/5,000 @ 60 RPM 450 GPM @ 860 Psi WOB 15 -18K ADT = 5.06, AST 1.54 02/07/2010 Continue to Drill f/ 684' - 2,790' MD - Completed 275 Bbl Unweighted Dilution @ 2,000 MD and 275 Bbl 11.0 PPG Dilution @ 2,600 MD to Bring MW to 9.6 PPG Page 1 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 684 1,571 SURFA( DRILL DDRL P Drill 13 1/2" Hole w/ Motor f/ 684' - 1,571' MD P/U 135, S/0 125, Rot 130 Torque On /Off 6,500/5,000 @ 70 RPM 550 GPM @ 1130 Psi WOB 15 -20 K ADT = 7.64, AST 5.25 12:00 00:00 12.00 1,571 2,790 SURFA( DRILL DDRL P Drill 13 1/2" Hole w/ Motor f/ 1571' - 2,790' MD - 275 Bbl Un- weighted Dilution @ 2,000' MD, 275 Bbl 11.0 PPG Spike Fluid @ 2,600' MD to Increase MW V 9.6 PPG P/U 133, S/0 125, Rot 130 Torque On /Off 8,000/6,000 @ 80 RPM 700 GPM @ 2100 Psi WOB 15 -25 K ADT = 7.64, AST 5.25 02/08/2010 Continue to Drill f/ 2,790' - 3,550' MD (TD) 2,472' TVD - CBU X3 - BROOH V 900' MD, CBU X4 on Last 2 Stands - RIH on Elevators V 3,550' MD - CBU X3 - OWFF (Static) - POOH on TT V 3,188' MD 00:00 12:00 12.00 2,790 3,378 SURFA( DRILL DDRL P Drill 13 1/2" Hole w/ Motor f/ 2790' - I 3378' MD - Pump Bit Balling Sweep @ 3,000' MD Consisting of 7.5 PPB Nut Plug, Screen Kleen, & Mud (No Effect), Pump a Second Sweep w/ Nut Plug Concentration Increased V 12.5 PPB; ROP Increased - Completed a 275 Bbl Dilution to Maintain Temperature - began Adding Nut Plug @ 1 Sack Every 5 Minutes for Bit Balling Prevention in Lower Clays P/U 125, S/O 118, Rot 125 Torque On /Off 8,500/7,000 @ 70 RPM 700 GPM @ 2380 Psi WOB 15 -25 K ADT = 7.89, AST = 1.2 12:00 13:30 1.50 3,378 3,550 SURFA( DRILL DDRL P Drill 13 1/2" Hole w/ Motor f/ 3378' - 3550' MD P/U 125, S/O 118, Rot 125 Torque On /Off 9,000/7,000 @ 70 RPM 700 GPM @ 2420 Psi WOB 15 -25 K ADT = 1.49, AST = 0.0 13:30 14:30 1.00 3,550 3,550 SURFA( DRILL CIRC P CBU X3 - 750 GPM @ 2550 Psi w/ 80 RPM OWFF (Static) Page 2 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 20:00 5.50 3,550 900 SURFA( DRILL REAM P BROOH f/ 3,550 - 900' MD - 700 GPM @ 70 RPM, Slowed to 500 GPM f/ the Base of Permafrost Up - Back Ream Final 2 Stands Slow to Allow Time for 4 Bottoms Up - Hole Continuously Unloaded Hockey Puck Sized Clay Cuttings and Sand for the First 2 Bottoms Up then Cleaned Up Significantly - OWFF (Static) 20:00 21:15 1.25 900 3,550 SURFA( DRILL TRIP P RIH on Elevators t/ 3,550' MD 21:15 23:00 1.75 3,550 3,550 SURFA( DRILL CIRC P CBU X3 - 700 GPM @ 2280 Psi w/ 70 RPM - Hole Unloaded Cuttings Mostly Sand and Clay for the First Bottoms Up Circulation, Cuttings Load was Very Light for the Remaining 1 1/2 Bottoms Up 23:00 00:00 1.00 3,550 3,188 SURFA( DRILL TRIP P OWFF (Static) - POOH on TT t/ 3,188' MD 02/09/2010 Continue to POOH f/ 3188', work through tight spot @ 1255', circulate, continue to POOH, PJSM, L/D BHA #1, clean floor, RU to run 10 -3/4" csg, PJSM, Run 10 -3/4" 45.5 ppf L -80 BTCM csg to 115', lay down jt #4(couldn't get pass 115'), circ w/ Frank's fillup tool- washing down f/ 115' to 155', continue to run csg to 1793', CBU, con't running casing f/ 1793' to 3540', rig down Frank's tool, install Dowell cement head, establish circulation, stage rate f/ 3 to 7 bpm, circ and cond mud f/ cementing, 809 bbls pumped. Pump 125 bbls of 9.8 ppg mud w/ nut plug marker, then 35 bbls Biozan water w/ nut plug. Dowell pumped 5 bbls water, pressure tested lines to 3000 psi- good, bleed off pressure, drop bottom plug. Mix and pump 48.14 bbls Mud Push II spacer (10.5 ppg), pumping 6 bpm w/ 260 psi. Mix and pump 467.27 bbls (574 sx) AS lite lead cement (10.8 ppg)(4.57 cuft/sx) (21.23 gal water /sx), pumping 7.5 bpm w/ final pressure of 466 psi. Mix and pump 62.4 bbls (299 sx) Alpine tail cement (15.8 ppg)(1.17 cuft/sx) (5.105 qal water /sx), pumping 5.5 bpm w/ final pressure of 215 psi. Shut down, then drop top plug. Dowell kick out top plug w/ 20 bbls water, pumping 6 bpm w/ 50 psi. Turn over to the rig. Rig displace cement w/ #2 mud pump, 9.8 ppg mud. Pumping 8 bpm w/ initial 270 psi. After pumping 300 bbls, final rate of 8 bpm w/ 740 psi, slowed to 4 bpm w/ 480 psi initial/ 510 psi final, bumped plug at calculated strokes (3112strokes) (312.75 bbls) to 1260 psi. Held pressure f/ 5 minutes. CIP @ 2111 hrs 2/9/2010. Note: Reciprocated until 10.8 ppg cement was back to surface. Landed on hanger @ 2053 hrs (191 bbls mud displaced). Circulated 118 bbls of good 10.8 ppg cement to surface. Check floats- OK. Rig down Dowell cementing equipment. Observed fluid in the stack falling slowly. Allow cement in riser to fill below hanger for 45 minutes after bumping plug. Drop of approx 9 feet = 1.23 bbls. Flush stack. Pull, then lay down the FMC 10 -3/4" landing joint. Pre. to ND. 00:00 01:30 1.50 3,188 1,255 SURFA( DRILL TRIP P Continue to POOH on elevators from 3,188' to 1,255' - pulled 20K over @ 1,255' - Free PUW 130K SOW 120K 01:30 02:15 0.75 1,255 1,189 SURFA( DRILL CIRC P Establish circulation - staged pumps up to 500gpm /1040 psi /60 rpm - Worked pipe from 1285' to 1189' circulated hole clean - slight amount of cuttings across shakers 02:15 03:30 1.25 1,189 909 SURFA( DRILL TRIP P POOH on elevators from 1,189' to 909' - PUW 120K SOW 110K - flow check well, static 03:30 04:00 0.50 909 74 SURFA( DRILL TRIP P POOH on elevators from 909' to 74' - stood back HWDP and Flex collars 04:00 05:15 1.25 74 0 SURFA( DRILL PULD P PJSM: LD BHA #1 - LD bit, UBHO, FS, Antenna sub, Index sub, EM collar, stab & motor 05:15 05:45 0.50 0 0 SURFA( DRILL PULD P Clear tools from rig floor - clean up trip mess Page 3 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 07:00 1.25 0 0 SURFA( CASING RURD P PJSM - rig up to run 10 3/4" casing 07:00 07:15 0.25 0 0 SURFA( CASING SFTY P PreJob safety and Opts meeting on running casing 07:15 08:15 1.00 0 115 SURFA( CASING RNCS P Run 10 3/4 ", 45.5 ", L -80 BTC -M casing - Silver bullet FS, 2 joints, Halliburton FC, 2 jts of casing - could not pass 115' - 08:15 09:00 0.75 115 115 SURFA( CASING CIRC T Laid down joint #4 - Confirmed ability to circulate through fill up tool - Stabbed into joint #3 - established circ and checked floats, ok - MU jnt#4 09:00 12:15 3.25 115 1,793 SURFA( CASING RNCS P Wash down from 115' to 155' - 3.5 bpm / 180 psi - slight resistance for ten feet - no furhter problem - Continue to run 10 3/4" casing from 155' to 1793' (44 jts total) PUW 140K SOW 125K 12:15 12:45 0.50 1,793 1,793 SURFA( CASING CIRC P Establish circulation 3.5 bpm / 280 psi - stage pumps up to 6.1 bpm CBU - FCP= 470 psi PUW 140K SOW 125K 12:45 15:15 2.50 1,793 3,540 SURFA( CASING RNCS P Run 10 3/4" casing from 1,793' to 3,497 (86 jts. total) - MU FMC fluted casing hanger and Landing joint - land casing with shoe @ 3,540', FC @ 3,461' 15:15 16:00 0.75 3,540 3,540 SURFA( CEMEN' RURD P RD fill up tool - Blow down top drive - Install cement head and lines 16:00 18:15 2.25 3,540 3,540 SURFA( CEMEN CIRC P Establish circulation, pumping 3 bpm w/ 300 psi. Stage pumps up to 7.0 bpm w/ 380 psi. Pumped a total of 809 bbls. Final mud properties: weight 9.8 ppg, PV/YP 19/19. Note: Held pre job safety meeting on cement job while circulating. Reciprocated 15' to 20'. 18:15 18:45 0.50 3,540 3,540 SURFA( CEMEN' CIRC P Rig pumped 125 bbls of 9.8 ppg mud with nut plug marker, followed with 35 bbls Biozan with nut plug marker (8.5 ppg). Pumping 6 bpm w/ 310 psi. Reciprocated 15' to 20'. PU wt 200k, SO wt 155k. Page 4 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 20:24 1.65 3,540 3,540 SURFA( CEMEN" PUCM P Dowell pumped 5 bbls water, pressure tested lines to 3000 psi - good, bleed off pressure, drop bottom plug. Mix and pump 48.14 bbls Mud Push II spacer (10.5 ppg), pumping 6 bpm w/ 260 psi. Mix and pump 467.27 bbls (574 sx) AS lite lead cement (10.8 ppg)(4.57 cuft/sx) (21.23 gal water /sx), pumping 7.5 bpm w/ final pressure of 466 psi. Mix and pump 62.4 bbls (299 sx) Alpine tail cement (15.8 ppg)(1.17 cuft/sx) (5.105 gal water /sx), pumping 5.5 bpm w/ final pressure of 215 psi. Shut down, then drop top plug. 20:24 20:30 0.10 3,540 3,540 SURFA( CEMEN" DISP P Dowell kick out top plug w/ 20 bbls water, pumping 6 bpm w/ 50 psi. Turn over to the rig. 20:30 21:15 0.75 3,540 3,540 SURFA( CEMEN" DISP P Rig displace cement w/ #2 mud pump, 9.8 ppg mud. Pumping 8 bpm w/ initial 270 psi. After pumping 300 bbls, final rate of 8 bpm w/ 740 psi, slowed to 4 bpm w/ 480 psi initial/ 510 psi final, bumped plug at calculated strokes (3112strokes) (312.75 bbls) to 1260 psi. Held pressure f/ 5 minutes. CIP @ 2111 hrs 2/9/2010. Note: Reciprocated until 10.8 ppg cement was back to surface. Landed on hanger @ 2053 hrs (191 bbls mud displaced). Circulated 118 bbls of good 10.8 ppg cement to surface. 21:15 22:00 0.75 3,540 3,540 SURFA( CEMEN" RURD P Check floats - OK. Rig down Dowell cementing equipment. Observed fluid in the stack falling slowly. Allow cement in riser to fill below hanger for 45 minutes after bumping plug. Drop of approx 9 feet = 1.23 bbls. 22:00 23:00 1.00 3,540 0 SURFA( DRILL PULD P Flush stack. Pull, then lay down the FMC 10 -3/4" landing joint. 23:00 00:00 1.00 0 0 SURFA( DRILL OTHR P Clean and clear rig floor. Pull the mouse hole to prepare for nippling down. Page 5 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/10/2010 24 hr Summary Pre job safety meeting, nipple down surface riser, install FMC Gen 2 wellhead, align head, test metal to metal seal to 1000 psi f/ 10 minutes, PJSM, NU BOPE, PJSM, PU /MU/ Stand back 5" drill pipe, RU to test ROPE, set lower test plug, fill stack and choke manifold. PJSM. Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Accumulator test performed: initial pressure 3000 psi, 1700 psi after operating. Recovery time test of 31 seconds for 200 psi build up and 2 minutes 25 seconds for full charge. Nitrogen bottles average 1650 psi. Electrician tested gas alarms. Rig down testing equipment. Test plug took 30k to pull free. Attempt to set wear bushing. Pushed down last 4 -1/2" w/ 15k to land. Pulled w/ 15k over to pull. Inspect wear bushing w/ no signs of markings. RU then wash stack w/ stack washing tool, loosen turnbuckles on the stack. Run in 45', wash stack twice w/ 700 gpm- 420 psi. RU, then run wear bushing, took 15k to push last 4 -1/2" in. RILDS. Blow down choke and kill lines and choke manifold. Note: Upper Lockdown screws to rig floor= 30.70'. Wear bushing 4.33' long, 10" ID x 10 -3/4" max OD. 00:00 00:15 0.25 0 0 SURFA( WHDBO SFTY P Pre job safety meeting on nipple down surface riser. 00:15 01:00 0.75 0 0 SURFA( WHDBO NUND P Nipple down surface riser. 01:00 02:00 1.00 0 0 SURFA( WHDBO NUND P Remove FMC quick connect. Install FMC Gen 2 wellhead, align head. 02:00 02:15 0.25 0 0 SURFA( WHDBO PRTS P Test metal to metal seal to 1000 psi f/ 10 minutes. 02:15 02:30 0.25 0 0 SURFA( WHDBO SFTY P PJSM on NU BOPE. 02:30 03:45 1.25 0 0 SURFA( WHDBO NUND P NU 13 -5/8" BOPE. 03:45 04:00 0.25 0 0 SURFA( DRILL SFTY P PJSM on PU /MU/ Stand back 5" drill pipe. 04:00 16:00 12.00 0 0 SURFA( DRILL PULD P PU /MU/ Stand back 5" drill pipe. PU and stood back 123 stands. 16:00 16:30 0.50 0 0 SURFA( WHDBO RURD P RU to test BOPE, set lower test plug, fill stack and choke manifold. 16:30 16:45 0.25 0 0 SURFA( WHDBO SFTY P PJSM on testing BOPE. 16:45 20:30 3.75 0 0 SURFA( WHDBO BOPE P Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Accumulator test performed: initial pressure 3000 psi, 1700 psi after operating. Recovery time test of 31 seconds for 200 psi build up and 2 minutes 25 seconds for full charge. Nitrogen bottles average 1650 psi. Electrician tested gas alarms. Page 6 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 0 0 SURFA( WHDBO BOPE P Rig down testing equipment. Lower test plug took 30k to pull free w/ the blocks. 21:00 22:00 1.00 0 0 SURFA( DRILL OTHR T Attempt to set wear bushing. Pushed down last 4 -1/2" w/ 15k to land. RILDS. Loosen LDS's. Pulled wear bushing free w/ 15k over to pull free. Inspect wear bushing w/ no signs of markings. 22:00 22:30 0.50 0 0 SURFA( DRILL OTHR T RU, then wash stack w/ stack washing tool, loosen turnbuckles on the stack. Run in 45' of a stand, wash stack twice w/ 700 gpm- 420 psi. 22:30 22:45 0.25 0 0 SURFA( DRILL OTHR T Blow down the top drive. 22:45 23:00 0.25 0 0 SURFA( DRILL OTHR T RU, then run FMC wear bushing. Pushed down w/ 15k the last 4 -1/2" to land. RILDS. Note: Upper Lockdown screws to rig floor= 30.70'. Wear bushing 4.33' long, 10" ID x 10 -3/4" max OD. 23:00 23:15 0.25 0 0 SURFA( DRILL RURD P Rig down FMC wear ring running tool and lay down the test joint. 23:15 00:00 0.75 0 0 SURFA( DRILL OTHR P Blow down the choke manifold, choke and kill lines. 02/11/2010 PJSM, PU /MU BHA #2, upload MWD, con't PU BHA #2, shallow pulse test @ 382', PU 5" dp f/ shed- RIH on top of BHA #2 to 3326', PJSM, slip and cut 60' of 1 -3/8" drilling line. PJSM, test 10 -3/4" 45.5 ppf L -80 BTC -m casing to 3500 psi- good test, rig down lines, wash /Ream f/ 3326' to top of cement at 3454'. Drill cement f/ 3454' to 3460', float plugs, float collar @ 3461', cement to float shoe 3537.86' to 3540.16'. Clean out rat hole from 3540' to 3550' (2471.95' ND). Drill 20' of new hole w/ 9 -7/8" bit and Sperry Sun 7600 GeoPilot ser # TL212. Actual drilling time .27 hrs. Circulate and condition mud for LOT /FIT test. Pumping 750 gpm w/ 2730 psi. Perform FIT to 15.6 ppg w/ 9.6 ppg mud and 1070 psi applied pressure. 10 -3/4" shoe at 3540.16' (2468.61' ND). Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 3570" to 4562' (2815' ND). Actual drilling time 6.47 hrs. Drill w/ 5 to 15k weight on bit. Pumping 650 to 750 gpm w/ 1670 to 2270 psi. Rotate 100 to 150 rpm w/ 8.5 to 10k ft lbs of torque on bottom and 7.5 to 8.5k ft lbs off bottom. ECD's 9.86 to 10.51 ppg. PU wt 150k, SO wt 115k, Rot wt 130k. Note: Changed over mud to new LSND mud 9.6 ppg after FIT, while drilling ahead. Pump bit balling sweeps flozan and 5 ppb nut plug) every three stands (3915', 4230', 4576'). Increase of 25 to 30% cuttings was seen at the shakers. 00:00 00:15 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on picking up BHA #2. 00:15 01:15 1.00 0 98 SURFA( DRILL PULD P Pick up/ Make up BHA #2 (9 -7/8" bit w/ GeoPilot) to 98'. 01:15 02:15 1.00 98 98 SURFA( DRILL PULD P Upload Sperry Sun MWD. 02:15 03:00 0.75 98 382 SURFA( DRILL PULD P Continue to PU /MU BHA #2 to 382'. 03:00 03:30 0.50 382 382 SURFA( DRILL DHEQ P Shallow pulse test MWD tools @ 382'. Pumping 650 gpm w/ 1290 psi. 03:30 04:00 0.50 382 755 SURFA( DRILL PULD P PU 5" drill pipe f/ pipe shed and run in w/ BHA #2 f/ 382' to 755'. PU wt 110k, SO wt 107k. 04:00 06:30 2.50 755 3,326 SURFA( DRILL PULD P Continue to PU 5" drill pipe f/ pipe shed and run in w/ BHA #2 f/ 755' to 3326'. PU wt 150k, SO wt 110k. Fill pipe. Page 7 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 06:45 0.25 3,326 3,326 SURFA( RIGMN1 SFTY P Pre job safety meeting on cut and slip drilling line. 06:45 08:00 1.25 3,326 3,326 SURFA( RIGMN1 SVRG P Slip and cut 60' of 1 -3/8" drilling line. Circulate while cutting drilling line, pumping 5 bpm w/ 300 psi. Service the top drive. 08:00 08:15 0.25 3,326 3,326 SURFA( DRILL SFTY P Pre job safety meeting on testing casing. 08:15 09:00 0.75 3,326 3,326 SURFA( DRILL PRTS P Test 10 -3/4" 45.5 ppf L -80 BTC -m casing to 3500 psi f/ 30 minutes. Chart test. 09:00 09:30 0.50 3,326 3,326 SURFA( DRILL RURD P Rig down and blow down lines. 09:30 10:00 0.50 3,326 3,454 SURFA( DRILL COCF P Wash and ream f/ 3326' to tag top of cement at 3454'. Pumping 600 gpm w/ 1950 psi. Rotate 60 rpm w/ 8500 ft lbs of torque. 10:00 12:00 2.00 3,454 3,550 SURFA( CEMEN' DRLG P Drill cement f/ 3454' to 3460', float plugs, float collar @ 3461', cement to float shoe 3537.86' to 3540.16'. Clean out rat hole from 3540' to 3550' (2471.95' TVD). 12:00 12:15 0.25 3,550 3,570 SURFA( DRILL DDRL P Drill 20' of new hole w/ 9 -7/8" bit and Sperry Sun 7600 GeoPilot ser # TL212. Actual drilling time .27 hrs. 12:15 12:45 0.50 3,570 3,570 SURFA( DRILL CIRC P Circulate and condition mud for LOT /FIT test. Pumping 750 gpm w/ 2730 psi. 12:45 13:00 0.25 3,570 3,570 SURFA( DRILL OTHR P Blowdown the top drive. 13:00 13:15 0.25 3,570 3,570 SURFA( DRILL SFTY P Pre job safety meeting on performing FIT and rig up. 13:15 13:30 0.25 3,570 3,570 SURFA( DRILL FIT P Perform FIT to 15.6 ppg w/ 9.6 ppg mud and 1070 psi applied pressure. 10 -3/4" shoe at 3540.16' (2468.61' ND). 13:30 00:00 10.50 3,570 4,562 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 3570" to 4562' (2815' ND). Actual drilling time 6.47 hrs. Drill w/ 5 to 15k weight on bit. Pumping 650 to 750 gpm w/ 1670 to 2270 psi. Rotate 100 to 150 rpm w/ 8.5 to 10k ft lbs of torque on bottom and 7.5 to 8.5k ft lbs off bottom. ECD's 9.86 to 10.51 ppg. PU wt 150k, SO wt 115k, Rot wt 130k. Note: Changed over mud to new LSND mud 9.6 ppg after FIT, while drilling ahead. Pump bit balling sweeps (flozan and 5 ppb nut plug) every three stands (3915', 4230', 4576'). Increase of 25 to 30% cuttings was seen at the shakers. Page 8 of 33 • r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/12/2010 24 hr Summary Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 4562' to 5037 (2974' TVD). Actual drilling time 2.62 hrs. Hole packed off while backreaming @ 5037'. Circulate and backream f/ 5037' to 4944' while pumping a nut plug sweep, surface to surface. Continue to drill 9 -7/8" hole f/ 5037' to 7130' (3675' TVD). Actual drilling time 11.89 hrs. Note: Pump bit balling sweeps ( flozan and 5 ppb nut plug) at 5418', 5798', 6274' and 6850'. Increase of 10 to 20% cuttings was seen at the shakers. Performed 275 bbl dilutions at 5418', 6274' and 7000'. 00:00 03:30 3.50 4,562 5,037 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 4562' to 5037' (2974' TVD). Actual drilling time 2.62 hrs. Drill w/ 5 to 15k weight on bit. Pumping 750 gpm w/ 2280 to 2360 psi. Rotate 150 rpm w/ 9k ft lbs of torque on bottom and 7.5k ft lbs off bottom. ECD's 10.49 to 10.6ppg. PU wt 152k, SO wt 117k, Rot wt 142k. 03:30 04:15 0.75 5,037 5,037 INTRM1 DRILL CIRC P Hole packed off while backreaming. Reduce flow rate as required to minimize ECD's. Backream, setting back a stand. Pump a bit balling sweep surface to surface. Pumping 750 gpm w/ 2430 psi. Rotate 150 gpm w/ 8k ft lbs of torque. 04:15 12:00 7.75 5,037 5,830 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 5037' to 5830' (3240' TVD). Actual drilling time 4.75 hrs. Drill w/ 5 to 18k weight on bit. Pumping 750 gpm w/ 2430 to 2740 psi. Rotate 150 rpm w/ 9 to 10.5k ft lbs of torque on bottom and 8 to 8.5k ft lbs off bottom. ECD's 10.45 to 10.66 ppg. PU wt 160k, SO wt 133k, Rot wt 145k. Note: Pump bit balling sweeps flozan and 5 ppb nut plug) (5418' and 5798'). Increase of 10 to 20% cuttings was seen at the shakers. Performed 275 bbl mud dilution @ 5418'. 12:00 18:00 6.00 5,830 6,560 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 5830' to 6560' (3485' TVD). Actual drilling time 4.09 hrs. Drill w/ 5 to 15k weight on bit. Pumping 750 gpm w/ 2740 to 2950 psi. Rotate 150 rpm w/ 10 to 11.6k ft lbs of torque on bottom and 8 to 9.5k ft lbs off bottom. ECD's 10.5 to 10.73 ppg. PU wt 165k, SO wt 135k, Rot wt 150k. Note: Pump bit balling sweeps flozan and 5 ppb nut plug) (6274'). Increase of 10 to 20% cuttings was seen at the shakers. Performed 275 bbl mud dilution @ 6274'. Page 9 of 33 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 6,560 7,130 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 6560' to 7130' (3675' TVD). Actual drilling time 3.05 hrs. Drill w/ 5 to 12k weight on bit. Pumping 750 gpm w/ 2950 to 3230 psi. Rotate 150 rpm w/ 10.5 to 11.3k ft Ibs of torque on bottom and 8 to 8.3k ft Ibs off bottom. ECD's 10.75 to 10.97 ppg. PU wt 170k, SO wt 135k, Rot wt 150k. Note: Pump bit balling sweeps ( flozan and 5 ppb nut plug) (6850'). Increase of 10 to 20% cuttings was seen at the shakers. Performed 275 bbl mud dilution @ 7000'. 02/13/2010 Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 7130' to 7415' (3771' TVD). Actual drilling time 1.55 hrs. Circulate and backream f/ 7415' to 7320' while pumping a nut plug sweep, surface to surface to reduce ECD's. Initial 11.01 ppg, final 10.64 ppg. Continue to drill 9 -7/8" hole f/ 7415' to 9670' (4527' TVD). Actual drilling time 12.73 hrs. Note: Pump bit balling sweeps ( flozan and 5 ppb nut plug) at 7230', 8082', 8580'. No increase in cuttings was seen at the shakers. Performed 550 bbl dilution at 7600', then 275 bbl dilutions at 8090', 8600', and 9223'. Note: Generator f/ Solids Control van not working 2 -14 -2010 @ 0230 hrs. 00:00 01:45 1.75 7,130 7,415 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 7130' to 7415' (3771' TVD). Actual drilling time 1.55 hrs. Drill w/ 5 to 10k weight on bit. Pumping 750 gpm w/ 3040 to 3150 psi. Rotate 150 rpm w/ 11.3 to 11.7k ft Ibs of torque on bottom and 8.4 to 8.7k ft Ibs off bottom. ECD's 10.97 to 11.01 ppg. PU wt 170k, SO wt 140k, Rot wt 155k. Note: Pump bit balling sweep flozan and 5 ppb nut plug) (7230'). Increase of 10 to 20% cuttings was seen at the shakers. 01:45 02:30 0.75 7,415 7,415 INTRM1 DRILL CIRC P Circulate a nut plug sweep surface to surface to clean up BHA and to reduce ECD's. Initial ECD's 11.1, final ECD's 10.64 while pumping 750 gpm w/ 3040 psi. Rotate 150 rpm w/ 9k ft Ibs of torque. Page 10 of 33 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 12:00 9.50 7,415 8,461 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 7415' to 8461' (4120' TVD). Actual drilling time 5.44 hrs. Drill w/ 5 to 15k weight on bit. Pumping 750 gpm w/ 3150 to 2980 psi. Rotate 150 rpm w/ 11.7 to 14k ft Ibs of torque on bottom and 8.7 to 11 k ft Ibs off bottom. ECD's 10.87 to 10.67 ppg. PU wt 195k, SO wt 138k, Rot wt 160k. Note: Pump bit balling sweeps ( flozan and 5 ppb nut plug) (8082'). Increase of 10 to 20% cuttings was seen at the shakers. Performed 550 bbl mud dilution @ 8090'. 12:00 18:00 6.00 8,461 9,032 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 8461' to 9032' (4311' TVD). Actual drilling time 4.43 hrs. Drill w/ 10 to 26k weight on bit. Pumping 750 gpm w/ 2800 to 3060 psi. Rotate 150 rpm w/ 13 to 15.5k ft Ibs of torque on bottom and 11 to 12.3k ft Ibs off bottom. ECD's 10.43 to 10.53 ppg. PU wt 215k, SO wt 135k, Rot wt 165k. Note: Pump bit balling sweeps flozan and 5 ppb nut plug) (8580'). Increase of 10 to 20% cuttings was seen at the shakers. Performed 275 bbl mud dilution @ 8600'. 18:00 00:00 6.00 9,032 9,670 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 9032' to 9670' (4527' TVD). Actual drilling time 2.86 hrs. Drill w/ 10 to 20k weight on bit. Pumping 750 gpm w/ 3000 to 3050 psi. Rotate 150 rpm w/ 15.5 to 16.5k ft Ibs of torque on bottom and 12.3 to 13k ft Ibs off bottom. ECD's 10.5 to 10.7 ppg. PU wt 220k, SO wt 137k, Rot wt 170k. Note: Performed 275 bbl mud dilution @ 9223'. 02/14/2010 Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 9670' to 12456 (5461' TVD). Actual drilling time 14.07 hrs. Note: Pump bit balling sweeps ( flozan and 7.5 ppb nut plug, .625 ppb SAPP) at 10363', 11632', and 11806'. Performed 275 bbl dilutions at 10550', 11315', and 12365'. Note: Generator f/ Solids Control van not working 2 -14 -2010 @ 0230 hrs. Replaced generator and back working @ 1400 hrs 2 -14 -2010. Page 11 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 9,670 10,459 INTRM1 DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 9670' to 10459' (4792' TVD). Actual drilling time 3.7 hrs. Drill w/ 10 to 25k weight on bit. Pumping 750 gpm w/ 2860 to 3090 psi. Rotate 150 rpm w/ 16.5 to 17.5k ft Ibs of torque on bottom and 13 to 14.5k ft Ibs off bottom. ECD's 10.7 to 10.88 ppg. PU wt 240k, SO wt 138k, Rot wt 176k. Note: Pump bit balling sweeps ( flozan and 7.5 ppb nut plug, .625 ppb SAPP) @ 10363'. 06:00 12:00 6.00 10,459 11,140 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 10459' to 11140' (5021' TVD). Actual drilling time 3.1 hrs. Drill w/ 12 to 20k weight on bit. Pumping 750 gpm w/ 2940 to 3200 psi. Rotate 150 rpm w/ 17.5 to 18.5k ft Ibs of torque on bottom and 14.5 to 15.5k ft Ibs off bottom. ECD's 10.85 to 10.10.83 ppg. PU wt 245k, SO wt 135k, Rot wt 177k. Note: Performed 275 bbl mud dilution @ 10550'. 12:00 18:00 6.00 11,140 11,886 INTRM1 DRILL DDRL P Drill 9-7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 11140' to 11886' (5271' TVD). Actual drilling time 4.25 hrs. Drill w/ 15 to 27k weight on bit. Pumping 750 gpm w/ 3230 to 2940 psi. Rotate 150 rpm w/ 18 to 19k ft Ibs of torque on bottom and 15 to 16.5k ft Ibs off bottom. ECD's 10.88 to 10.51 ppg. PU wt 260k, SO wt 144k, Rot wt 183k. Note: Pump bit balling sweeps ( flozan and 7.5 ppb nut plug, .625 ppb SAPP) @ 11632' and 11806'. Performed 275 bbl mud dilution @ 11315'. 18:00 00:00 6.00 11,886 12,456 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 11886' to 12456' (5461' TVD). Actual drilling time 3.032 hrs. Drill w/ 12 to 22k weight on bit. Pumping 750 gpm w/ 2940 to 2680 psi. Rotate 150 rpm w/ 18.5 to 20.5k ft Ibs of torque on bottom and 16.5 to17 k ft Ibs off bottom. ECD's 10.51 to 10.41 ppg. PU wt 270k, SO wt 145k, Rot wt 186k. Note: Performed 275 bbl mud dilution @ 12365'. 02/15/2010 Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 12456' to 14785' (6243' TVD). Actual drilling time 13.11 hrs. Note: Pump bit balling sweeps ( flozan and 6.25 ppb nut plug, .625 ppb SAPP) at 13020', 13578', and 14625'. Performed 275 bbl dilutions at 13764', and 14785'. Page 12 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 12,456 13,633 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 12456' to 13633' (5858' TVD). Actual drilling time 6.35 hrs. Drill w/ 10 to 25k weight on bit. Pumping 750 gpm w/ 2780 to 3170 psi. Rotate 150 rpm w/ 20.5 to 22.5k ft Ibs of torque on bottom and 17.0 to 19 k ft lbs off bottom. ECD's 10.41 to 10.64 ppg. PU wt 265k, SO wt 151k, Rot wt 195k. Note: Pump bit balling sweeps flozan and 6.25 ppb nut plug, .625 ppb SAPP) @ 13020' and 13578'. 12:00 18:00 6.00 13,633 14,278 INTRMI DRILL DDRL P Drill 9-7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 13633' to 14278' (6073' TVD). Actual drilling time 3.88 hrs. Drill w/ 12 to 25k weight on bit. Pumping 750 gpm w/ 2960 to 3170 psi. Rotate 150 rpm w/ 20.5 to 18k ft lbs of torque on bottom and 14.5 to 12.5 k ft Ibs off bottom. ECD's 10.52 to 10.48 ppg. PU wt 246k, SO wt 165k, Rot wt 200k. Note: Performed 275 bbl mud dilution @ 13764'. 18:00 00:00 6.00 14,278 14,785 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 14278' to 14785' (6243' TVD). Actual drilling time 2.88 hrs. Drill w/ 12 to 25k weight on bit. Pumping 750 gpm w/ 3050 to 3140 psi. Rotate 150 rpm w/ 18 to 19.5k ft Ibs of torque on bottom and 12.5 to 13.5 k ft Ibs off bottom. ECD's 10.48 to 10.52 ppg. PU wt 255k, SO wt 165k, Rot wt 200k. Note: Pump bit balling sweeps ( flozan and 6.25 ppb nut plug, .625 ppb SAPP) @ 14625'. Performed 275 bbl mud dilution @ 14785'. 02/16/2010 Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 14785' to 15342' (6432' TVD). Actual drilling time 3.35 hrs. Circulate 6 BU while setting back a stand every 1 hr to 14785'. Pumping 750 gpm w/ 3160 psi initial, final pressure 3150 psi., rotating 140 rpm w/ 16k ft Ibs of torque. Monitor well @ 14785' - static, trip in to 15251', wash to TD @ 15342', continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 15342' to 16418' (6777' TVD). Actual drilling time 7.47 hrs. Note: Converted to Inhibycol System @ 15385' w/ 275 bbl 9.4 ppg LSND, 275 bbls 9.8 ppg spike fluid @ 36% Inhibycol; 275 bbls black water spike w/ Soltex, and Resinex to bring active concentrations to 6 ppb Soltex and 4 ppb Resinex. Added Lotorq and Lube 776 to increase system to 4 %; reduced torque from 23K at 15617' to 20.5K at 16400'.Adding 18% Inhibycol 8.4 ppg spike fluid to active @ 4bph. Page 13 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 14,785 15,342 INTRMI DRILL DDRL P Drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 14785' to 15342' (6432' TVD). Actual drilling time 3.35 hrs. Drill w/ 10 to 20k weight on bit. Pumping 750 gpm w/ 2900 to 3160 psi. Rotate 150 rpm w/ 19.5 to 20.5k ft Ibs of torque on bottom and 13.5 to 14.5 k ft Ibs off bottom. ECD's 10.48 to 10.51 ppg. PU wt 270k, SO wt 165k, Rot wt 210k. Note: Pump bit balling sweeps ( flozan and 6.25 ppb nut plug, .625 ppb SAPP) @ 15342'. 04:30 10:45 6.25 15,342 14,785 INTRM1 DRILL CIRC P Circulate 6 BU while setting back a stand every 1 hr from 15342' to 14785'. Pumping 750 gpm w/ 3160 psi initial, final pressure 3150 psi., rotating 140 gpm w/ 16k ft Ibs of torque. 10:45 11:00 0.25 14,785 14,785 INTRM1 DRILL OWFF P Blow down the top drive. Monitor well for flow @14785' - static. 11:00 11:15 0.25 14,785 15,251 INTRMI DRILL TRIP P Trip in the hole from 14785' to 15251'. PU wt 265k, SO wt 160k. 11:15 11:30 0.25 15,251 15,342 INTRMI DRILL WASH P Wash and ream from 15251' to 15342'. 11:30 12:00 0.50 15,342 15,373 INTRM1 DRILL DDRL P Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 15342' to 15373' (6443' TVD). Actual drilling time .24 hrs. 12:00 18:00 6.00 15,373 15,895 INTRM1 DRILL DDRL P Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 15373' to 15895' (6614' TVD). Actual drilling time 3.61 hrs. Note: Converted to Inhibycol System @ 15385' w/ 275 bbl 9.4 ppg LSND, 275 bbls 9.8 ppg spike fluid @ 36% Inhibycol; 275 bbls black water spike w/ Soltex, and Resinex to bring active concentrations to 6 ppb Soltex and 4 ppb Resinex. Added Lotorq and Lube 776 to increase system to 4 %; reduced torque from 23K at 15617' to 20.5K at 16400'.Adding 18% Inhibycol 8.4 ppg spike fluid to active @ 4bph. 18:00 00:00 6.00 15,895 16,418 INTRM1 DRILL DDRL P Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 15895' to 16418' (6777' TVD). Actual drilling time 3.62 hrs. 02/17/2010 Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 16418' to 17900' (TD of intermediate , hole)(7074.67' TVD). Drilled 14350' of 9 -7/8" hole, total hrs on bit 85.46 (167.91ft/hr avg). Landed at 82.65 deg, 322.55 deg azimuth. Circulate 4.3 BU while backreaming each stand approx 6 times each (20' /min). Set back a stand each hr from 17900' to 17387' at midnight. Pumping 736 gpm w/ 3920 psi initial, final pressure 3790 psi., rotating 140 rpm w/ 19k ft Ibs of initial and 17k ft Ibs of torque final. ECD's initial 10.65 ppg, at midnight 10.5 ppg. Note: Performed 275 bbl mud dilution while drilling at 17100'. Page 14 of 33 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 16,418 17,012 INTRM1 DRILL DDRL P Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 16418' to 17012' (6926' TVD). Actual drilling time 4.55 hrs. Total hrs on the bit 78.08 hrs. Drill w/ 12 to 20k weight on bit. Pumping 750 gpm w/ 3880 to 3930 psi. Rotate 150 rpm w/ 20 to 21.5k ft Ibs of torque on bottom and 14.0 to 17 k ft Ibs off bottom. ECD's 10.77 to 10.84 ppg. PU wt 300k, SO wt 155k, Rot wt 211k. 06:00 12:00 6.00 17,012 17,430 INTRM1 DRILL DDRL P Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 17012' to 17430' (7001' TVD). Actual drilling time 3.19 hrs. Total hrs on the bit 81.27 hrs. Drill w/ 12 to 20k weight on bit. Pumping 736 gpm w/ 3930 to 3920 psi. Rotate 150 rpm w/ 21 to 22.5k ft Ibs of torque on bottom and 16.5 to 17.5 k ft Ibs off bottom. ECD's 10.77 to 10.7 ppg. PU wt 300k, SO wt 157k, Rot wt 215k. Note: Performed 275 bbl mud dilution @ 17100'. 12:00 17:45 5.75 17,430 17,900 INTRM1 DRILL DDRL P Continue to drill 9 -7/8" hole w/ Sperry Sun GeoPilot (ser # TL212) from 17430' to 17900' (7074.67' TVD). Actual drilling time 4.19 hrs. Total hrs on the bit 85.46 hrs. Drill w/ 12 to 27k weight on bit. Pumping 736 gpm w/ 3920 to 3960 psi. Rotate 150 rpm w/ 22.5k ft Ibs of torque on bottom and 16.5 to 18 k ft Ibs off bottom. ECD's 10.7 to 10.65 ppg. PU wt 305k, SO wt 160k, Rot wt 220k. 17:45 00:00 6.25 1,790 17,387 INTRM1 DRILL CIRC P Circulate and condition mud and hole. Circulate 4.3 BU (54000 strokes). Pumping 736 gpm w/ 3920 to 3790 psi. Rotate 140 rpm w/ 19k to 17 k ft Ibs of torque. Reciprocate from 17900' to 17387'. Work each stand about 20' /min, 6 times each stand. Set back a stand every hour. ECD's initial 10.65 ppg, at midnight 10.5 ppg. Page 15 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/18/2010 24 hr Summary Con't to circ f/ 4.3 to 6 BU while backreaming each stand approx 6 times each (20' /min). Set back a stand each hr from 17387' to 17204'. Pumping 736 gpm w/ 3790 psi initial, final pressure 3850 psi., rotating 140 rpm w/ 17k ft lbs of initial and 19k ft lbs of torque final. ECD's initial 10.5 ppg to 10.45 ppg. Note: Performed a 275 bbl mud dilution while circulating @ 17330'. Backream out of the hole f/ 17204' to 15343'. Circulate 3 BU while working a stand 6 times (20' /min), setting back a stand every hr from 15343' to 15065'. Blow down the top drive, monitor well- static. Trip in the hole f/ 15065' to 17853'. Precautionary wash and ream f/ 17853' to 17900'. Circulate 4 BU while working from 17900' to 15993'. Setting back 3 to 4 stands every 1 hr. Pumping 736 gpm w/ 3900 psi., final 3550 psi, no rotation. Moniotr well- static, blow down top drive. Trip in f/ 15993' to 17667', precautionary wash to 17853', precautionary ream to 17900'. Circulate 1/2 BU pumping 740 gpm w/ 3650 psi, rotate 140 to 125 rpm w/ 19k ft Ibs of torque. Obtain slow pump rates. Load drill pipe w/ casing running pill, chase to the bit. Pull out of the hole laving in the casino runnino pill in the 9 -7/8" open hole. pulling 30' /min, pumping 3 bpm from 17900' to 15525'. Note: Casing running pill consists of active mud, 5 ppb each:SafeCarb 40, SafeCarb 250, G Seal, Alpine Drill Beads, and 6 pDb Soltex, 4 ppb Resinex, 6% LoTorq /Lube 776. 00:00 02:15 2.25 17,387 17,204 INTRM1 DRILL CIRC P Continue to circulate and condition mud and hole. Circulate from 4.3 BU (54000 strokes) to 6 BU (75348 strokes). Pumping 736 gpm w/ 3790 to 3850 psi. Rotate 140 rpm w/ 17k to 19 k ft Ibs of torque. Reciprocate from 17387' to 17204'. Work each stand about 20' /min, 6 times each stand. Set back a stand every hour. ECD's initial 10.5 ppg, final 10.45 PPg• Note: Performed 275 bbl mud dilution while circulating @ 17330'. 02:15 02:30 0.25 17,204 17,204 INTRMI DRILL OWFF P Monitor well for flow @ 17204' - static. 02:30 06:00 3.50 17,204 15,343 INTRM1 DRILL REAM P Backream out of the hole f/ 17204' to 15343'. Pumping 736 gpm w/ 3850 psi initial and 3630 psi final. Rotate 140 rpm w/ 17k ft Ibs of torque. ECD's 10.45 ppg to 10.43 ppg. Pulling speed 25 to 30' /min. 06:00 09:15 3.25 15,343 15,065 INTRM1 DRILL CIRC P Circulate and condition mud and hole. Circulate 3 BU minimum (32292 strokes). Pumping 750 gpm w/ 3850. Rotate 140 rpm w/ 19k to 18k ft Ibs of torque. Reciprocate from 15343' to 15065'. Work each stand about 20' /min, 5 times each stand. Set back a stand every hour. Initial ECD's 10.6 ppg, final ECD's 10.42 PPg• 09:15 09:30 0.25 15,065 15,065 INTRMI DRILL OWFF P Blow down the top drive. Monitor well- static. 09:30 11:45 2.25 15,065 17,853 INTRMI DRILL TRIP P Trip in the hole from 15065' to 17853'. PU wt 285k, SO wt 155k @ 17853'. 11:45 12:00 0.25 17,853 17,900 INTRM1 DRILL REAM P Precautionary wash and ream from 17853' to 17900'. 12:00 18:00 6.00 17,900 15,993 INTRM1 DRILL CIRC P Circulate a minimum 4 BU ( 50232 strokes) while setting back 3 to 4 stands every 1 hr from 17900' to 15993'. Pumping 736 gpm w/ 3900 psi initial, 750 gpm w /final pressure 3550 psi., no rotation. Page 16 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:15 0.25 15,993 15,993 INTRM1 DRILL OWFF P Blow down the top drive. Monitor well- static. 18:15 19:15 1.00 15,993 17,667 INTRM1 DRILL TRIP P Trip in the hole from 15993' to 17667'. PU wt 290k, SO wt 160k @ 17853'. 19:15 19:30 0.25 17,667 17,853 INTRM1 DRILL WASH P Precautionary wash in the hole from 17667' to 17853'. Pumping 612 to 117 gpm w/ 2660 to 3440 psi. 19:30 19:45 0.25 17,853 17,900 INTRM1 DRILL REAM P Precautionary ream in the hole from 17853' to 17900'. Pumping 740 gpm w/ 3600 psi. Rotate 140 rpm w/ 20k ft Ibs of torque. 19:45 20:15 0.50 17,900 17,900 INTRM1 DRILL CIRC P Circulate 1/2 bottom's up. Pumping 740 gpm w/ 3650 psi. Rotate 140 to 125 rpm w/ 19k ft Ibs of torque. Obtain slow pump rates. 20:15 20:45 0.50 17,900 17,900 INTRMI DRILL CIRC P Spot 260 bbls of casing running pill in the drill pipe, chase w/ 9.9 ppg mud to the bit. Pumping 730 to 450 gpm w/ 3800 to 1900 psi. Note: Casing running pill consists of active mud, 5 ppb each:SafeCarb 40, SafeCarb 250, G Seal, Alpine Drill Beads, and 6 ppb Soltex, 4 ppb Resinex, 6% LoTorq /Lube 776. 20:45 00:00 3.25 17,900 15,525 INTRMI DRILL TRIP P Pump out of the hole from 17900' to 15525'. Pumping 3 bpm w/ initial 450 psi, final 320 psi, pulling 30' /min, laying in the casing running pill in the 9 -7/8" open hole. Obtain PU and SO wt's every 20 stands per Rig Engineer. 02/19/2010 Con't to pull out of the hole laying in the casing running pill in the 9 -7/8" open hole, pulling 30' /min, pumping 3 bpm from 15525' to 14971'. Note: Casing running pill consists of active mud, 5 ppb each:SafeCarb 40, SafeCarb 250, G Seal, Alpine Drill Beads, and 6 ppb Soltex, 4 ppb Resinex, 6% LoTorq /Lube 776. Circulate and condition mud and hole: Perform 275 bbl mud dilution due to MBT above 20 and to weight up to 10.0 ppg. Work pipe from 14971' to 14690' while pumping 750 gpm w/ 3480 psi. Monitor well- static. Pull out of the hole on elevators from 14785' to 13390' wiping out tight spots (14491', 14368', 13900', 13800', 13340', 13310'). Pump out of the hole from 13390' to 13112'. Pumping 750 gpm w/ 3440 psi and no rotation. Wipe out tight spots (13340', 13310', 13124'). Backream out of the hole from 13112' to 12266'. Pumping 750 gpm w/ 3440 to 3000 psi. Rotate 120 rpm w/ 17 to 15k ft Ibs of torque. Wipe out tight spots (13098', 13047', 13015', 12921', 12755'). Continue to backream from 12266' to 7511' at midnight. Slowed pulling speed to 200' /hr because of increased ECD's from 9400' to 9200'. Note: Performed a 275 bbl mud dilution while backreaming at 8000' to 7700'. 00:00 00:45 0.75 15,525 14,971 INTRM1 DRILL TRIP P Pump out of the hole from 15525' to 14971'. Pumping 3 bpm w/ initial 450 psi, final 320 psi, pulling 30' /min, laying in the casing running pill in the 9 -7/8" open hole. Obtain PU and SO wt's every 20 stands per Rig Engineer. Note: Casing running pill consists of active mud, 5 ppb each:SafeCarb 40, SafeCarb 250, G Seal, Alpine Drill Beads, and 6 ppb Soltex, 4 ppb Resinex, 6% LoTorq /Lube 776. Page 17 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 03:15 2.50 14,971 14,785 INTRM1 DRILL CIRC P Circulate and condition mud and hole. Pumping 750 gpm w/ 3480 psi. Rotate 140 to 125 rpm w/ 17k. Work pipe setting back a stand every 45 minutes. Work hole from 14971' to 14690' while circulating. Note: Performed a 275 bbl dilution and weight mud to 10 ppg. 03:15 03:30 0.25 14,785 14,785 INTRM1 DRILL OWFF P Monitor well- static. Blow down the top drive. 03:30 06:00 2.50 14,785 13,390 INTRM1 DRILL TRIP P Pull out of the hole on elevators from 14785' to 13390'. At 13390': PU wt 250k, SO wt 150k. Monitor well on the trip tank. Wipe out tight spots at 14491', 14368', 13900', 13800'. After working pipe, no extra drag was seen. 06:00 06:15 0.25 13,390 13,390 INTRM1 DRILL TRIP P Attempt to pull out of the hole on elevators from 13390' to 13300'. Monitor well on the trip tank. P Wipe out tight spots at 13340', 9 13310'. Appears to be pushing mud when working down to wipe tight spots. 06:15 06:30 0.25 13,390 13,390 INTRM1 DRILL OWFF P Monitor well- static. 06:30 07:45 1.25 13,390 13,112 INTRM1 DRILL TRIP P Pump out of the hole from 13390' to 13112'. Pumping 750 gpm w/ 3430 psi. PU wt 230k, SO wt 150k. Wipe out tight spots at 13340', 13310', 13124'. Pulling tight. 07:45 12:00 4.25 13,112 12,266 INTRMI DRILL REAM P Back ream out of the hole from 13112' to 12266'. Pumping 750 gpm w/ 3440 psi. Rotate 120 rpm w/ 17 to 15k ft Ibs of torque. Wipe out tight spots at 13098', 13047', 13015', 12921', 12755'. 12:00 18:00 6.00 12,266 9,320 INTRM1 DRILL REAM P Back ream out of the hole from 12266' to 9320'. Pumping 750 gpm w/ 3440 psi initial and 3000 psi final. Rotate 120 rpm w/ 17 to 15k ft Ibs of torque. 18:00 00:00 6.00 9,320 7,511 INTRMI DRILL REAM P Back ream out of the hole from 9320' to 7511'. Pumping 750 gpm w/ 3000 psi initial and 2800 psi final. Rotate 120 rpm w/ 15 to 10k ft Ibs of torque. At 7511': PU wt 185k, SO wt 135k Slowed pulling speed to 200' /hr from 9400' to 9200' for higher ECD's. Note: Performed a 275 bbl dilution while backreaminq f/ 8000' to 7700'. Page 18 of 33 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/20/2010 24 hr summary Con't to backream out of the hole from 7511' to 6465' . Pumping 750 gpm w/ 2800 to 2850 psi. Rotate 120 rpm w/ 9 to 8.5k ft Ibs of torque. Note: Pumped nut plug sweep while backreaming @ 7400', 6654', Tight @ 6544'. Con't to backream out of the hole from 6465' to 5940' . Pumping 750 gpm w/ 2740 to 2750 psi. Rotate 120 rpm w/ 8.5 to 9k ft Ibs of torque. Con't to backream out of the hole from 5940' to 5128' . Pumping 750 gpm w/ 2740 and final 740 gpm w/ 3050 psi.. Rotate 120 rpm w/ 9 to 8k ft Ibs of torque. Con't to backream out of the hole from 5128' to 3992' . Pumping 750 gpm w/ 3050 and final 2550 psi.. Rotate 120 to 130 rpm w/ 8 to 6k ft lbs final torque. Note: Performed a 275 bbl dilution while backreaming f/ 4340'. 00:00 06:00 6.00 7,511 6,465 INTRM1 DRILL REAM P Back ream out of the hole from 7511' to 6465'. Pumping 750 gpm w/ 2800 psi initial and 2850 psi final. Rotate 120 rpm w/ 9 to 8.5k ft Ibs of torque. Note: Pumped nut plug sweep while backreaming @ 7400' and 6654', Tight @ 6544', run a stand in to 6654', then pump nut plug sweep, circ to surface. 06:00 12:00 6.00 6,465 5,940 INTRM1 DRILL REAM P Back ream out of the hole from 6465' to 5940'. Pumping 750 gpm w/ 2740 psi initial and 2750 psi final. Rotate 120 rpm w/ 8.5 to 9k ft Ibs of torque. 12:00 18:00 6.00 5,940 5,128 INTRM1 DRILL REAM P Back ream out of the hole from 5940' to 5128'. Pumping 750 gpm w/ 2740 psi initial and 740 gpm w/ 3050 psi final. Rotate 120 rpm w/ 9 to 8k ft Ibs of torque. 18:00 00:00 6.00 5,115 3,992 INTRM1 DRILL REAM P Back ream out of the hole from 5128' to 3992'. Pumping 740 gpm w/ 3050 psi initial and 2550 psi final. Rotate 120 to 135 rpm w/ 8k ft Ibs of torque initial and 6k ft Ibs final. Note: Performed a 275 bbl dilution while backreaming f/ 4340'. 02/21/2010 Con't to backream out of the hole from 3992' to 3516' . Pumping 750 gpm w/ 2550 and final 2500 psi.. Rotate 120 to 130 rpm w/ 6 to 5k ft Ibs final torque. ECD's 10.45 ppg. Circulate 2 bottom's up, then pump a 35 bbl hi vis weighted sweep w/ nut plug surface to surface + 1 bottom's up. Pumping 750 gpm w/ 2350 psi final. Rotate 120 rpm w/ 5k ft Ibs of torque. Final ECD's 10.36 ppg. Pre job safety meeting on cutting drilling line. Slip and cut 90' of 1 -3/8" drilling Iine.Monitor well- static, POOH on trip tank to 2946', Circulate 16 YP mud in casing, monitor well- static, POOH on trip tank to 2470', insufficient fill, monitor well, static, POOH pumping f/ 2470' to 629', blow down the top drive, POOH on the trip tank f/ 629' to 284'. Lay down (2) 5" HWDP and jars, UD (3) flex DC's, stab, and float sub to 94', Download MWD, break bit, finish UD BHA #2. Wash stack, blow down TD, Pull FMC wear bushing (Worn on one side), PJSM, change top pipe rams to 7 -5/8 ", set test plug, test to 250 psi low and 3500 psi high f/ 5 min each, chart test. Rig down testing equipment, install FMC thin wall casing wear bushing. Rig up to run 7 -5/8" 29.7 ppf L -80 BTC -mod casing. PJSM, Run 7 -5/8" casing: Pick up jt #1: Ray Oil tool 7 -5/8" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7 -5/8" x 9- 1/16 ") floating f/ collar to 10' above the shoe with stop ring. Thread lock joint #2 w/ 7 -5/8" x 9 -3/8" Volant Hydroform centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Thread lock jt #3 w/ Volant Hydroform centralizer floating f/ pin to10' above pin with stop ring. Baker lock Halliburton Baffle adapter, then Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were bakerlocked. Page 19 of 33 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 3,992 3,516 INTRMI DRILL REAM P Con't to backream out of the hole from 3992' to 3516' . Pumping 750 gpm w/ 2550 and final 2500 psi.. Rotate 120 to 130 rpm w/ 6 to 5k ft Ibs final torque. ECD's 10.45 ppg. 04:30 05:45 1.25 3,516 3,516 INTRM1 DRILL CIRC P Circulate 2 bottom's up, then pump a 35 bbl hi vis weighted sweep w/ nut plug surface to surface + 1 bottom's up. Pumping 750 gpm w/ 2350 psi final. Rotate 120 rpm w/ 5k ft Ibs of torque. Final ECD's 10.36 ppg. Note: Sweep 11 ppg, w/ 2 ppb Flozan, 5 ppb nut plug medium. 05:45 06:00 0.25 3,516 3,516 INTRM1 RIGMNT SFTY P Pre job safety meeting on cutting drilling line. 06:00 07:15 1.25 3,516 3,516 INTRMI RIGMNT SVRG P Slip and cut 90' of 1 -3/8" drilling line. Service rig. calibrate Totco EDMS for depth control. Circulate 211 gpm w/ 250 psi while cutting line. 07:15 07:30 0.25 3,516 3,516 INTRM1 DRILL OWFF P Monitorwell- static. 07:30 08:45 1.25 3,516 2,946 INTRM1 DRILL TRIP P Pull out of the hole on the trip tank from 3516' to 2946'. 08:45 09:15 0.50 2,946 2,946 INTRM1 DRILL CIRC P Circulate thinner 10 ppg mud in the 10 -3/4" casing for trip out. Yield point of 16, thinned w/ water and CF Desco. Pumping 750 gpm w/ 2190 psi. Rotate 100 rpm w/ 5k ft Ibs of torque. 09:15 09:30 0.25 2,946 2,946 INTRM1 DRILL OWFF P Monitor well- static. 09:30 10:15 0.75 2,946 2,470 INTRMI DRILL TRIP P Pull out of the hole on the trip tank from 2946' to 2470'. Insufficient fill. 10:15 10:30 0.25 2,470 2,470 INTRMI DRILL OWFF P Monitor well- static. 10:30 12:00 1.50 2,470 1,833 INTRMI DRILL TRIP P Pull out of the hole f/ 2470' to 1833', pumping 700 gpm w/ 1920 psi to 210 gpm w/ 230 psi. Lay down upper ghost reamer. 12:00 13:45 1.75 1,833 629 INTRM1 DRILL TRIP P Pull out of the hole, pumping 210 gpm w/ 250 psi. Lay down bottom ghost reamer. 13:45 14:00 0.25 629 629 INTRM1 DRILL OTHR P Blow down the top drive. 14:00 14:15 0.25 629 629 INTRM1 DRILL OWFF P Monitor well- static. 14:15 14:30 0.25 629 284 INTRM1 DRILL TRIP P Pull out of the hole from 629' to 284', monitor fill on the trip tank. 14:30 15:15 0.75 284 94 INTRMI DRILL PULD P Lay down (2) 5" HWDP and the jars, then (3) NM flex drill collars, stab and float sub to 94'. 15:15 16:00 0.75 94 94 INTRMI DRILL OTHR P Downlaod MWD, break bit. Flapper on float missing. 16:00 17:30 1.50 94 0 INTRMI DRILL PULD P Lay down BHA #2 from 94'. Page 20 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:15 0.75 0 0 INTRM1 DRILL CIRC P Make up stack washing tool on a stand of 5" drill pipe. Flush stack. Pumping 500 gpm w/ 180 psi. Work 4 times, up and down. Functioned upper and lower rams. also the annular. Blow down the top drive. 18:15 18:30 0.25 0 INTRM1 DRILL PULD P Blow down the top drive. Break stack washing tool, lay down, stand back a stand. 18:30 18:45 0.25 0 0 INTRM1 WHDBO OTHR P Make up 5" test joint and running /pulling tool f/ the FMC wear ring. Pull FMC wear ring w/ 15k over pull. Wear ring worn on one side. Will need new one f/ next well. 18:45 19:00 0.25 0 0 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top rams to 7 -5/8 ". 19:00 20:15 1.25 0 0 INTRMI WHDBO OTHR P Change upper pipe rams from 3 -1/2" x 6" variables to 7 -5/8" solid. 20:15 20:45 0.50 0 INTRMI WHDBO RURD P Pick up 7 -5/8" test joint. Set lower test plug. Rig up to test 7 -5/8" upper pipe rams. 20:45 21:15 0.50 0 0 INTRMI WHDBO BOPE P Test rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. 21:15 21:45 0.50 0 0 INTRM1 WHDBO PULD P Rig down testing equipment. Run FMC thin wall casing running wear bushing (10.75" ID). Lay down running tool and test joint. 21:45 23:00 1.25 0 0 INTRM1 CASING RURD P Rig up to run 7 -5/8" 29.7 ppf L -80 BTC -m casing. 23:00 23:30 0.50 0 0 INTRMI CASING SFTY P Pre job safety meeting on running 7 -5/8" 29.7 ppf L -80 BTC -m casing with both crews. 23:30 00:00 0.50 0 120 INTRMI CASING RNCS P Run 7 -5/8" casing: Pick up jt #1: Ray Oil tool 7 -5/8" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7 -5/8" x 9- 1/16 ") floating f/ collar to 10' above the shoe with stop ring. Thread lock joint #2 w/ 7 -5/8" x 9 -3/8" Volant Hydroform centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Thread lock jt #3 w/ Volant Hydroform centralizer floating f/ pin to10' above pin with stop ring. Baker lock Halliburton Baffle adapter, then Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were bakerlocked. 02/22/2010 Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 120' to 3525' (83 jts in the hole), circ 2+ BU (190 bbls), con't to run 7 -5/8" csg to 5525' (130 jts), circ 2 BU (250 bbls), con't to run csg to 7440' (175 jts), circ 2 BU (300 bbls), con't to run csg to 9555' (225 jts), circ 2+ BU (520 bbls), con't to run csg to 11670' (275 jts), circ 1.5 BU (670 bbls), con't to run csg to 13585' (320 jts). Page 21 of 33 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:45 5.75 120 3,525 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 120' to 3525' (83 jts in the hole). PU 137k, SO 130k. Obtain PU & SO wt's per rig engineer. 05:45 06:30 0.75 3,525 3,525 INTRMI CASING CIRC P Circulate 2+ BU 190 bbls. Stage up f/ 4 bpm w/ 250 psi to 7 bpm w/ 470 psi, 27% Totco flow meter. 06:30 08:45 2.25 3,525 5,525 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 3525' to 5525' (130 jts in the hole). PU wt 160k, SO wt 135k. Obtain PU & SO wt's per rig engineer. 08:45 09:30 0.75 5,525 5,525 INTRM1 CASING CIRC P Circulate 2 bottom's up, 250 bbls. Stage up f/ 3.5 bpm w/ 270 psi to 7 bpm w/ 540 psi, 23% Totco flow meter. 09:30 12:00 2.50 5,525 7440 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 5525' to 7440' (175 jts in the hole). PU wt 202k, SO wt 143k. Obtain PU & SO wt's per rig engineer. 12:00 12:45 0.75 7,440 7,440 INTRM1 CASING CIRC P Circulate 2- bottom's up, 300 bbls. Stage up f/ 4 bpm w/ 280 psi to 7 bpm w/ 590 psi. 12:45 15:30 2.75 7,440 9,555 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 7440' to 9555' (225 jts in the hole). PU wt 240k, SO wt 150k. Obtain PU & SO wt's per rig engineer. 15:30 17:00 1.50 9,555 9,555 INTRMI CASING CIRC P Circulate 2+ bottom's up, 520 bbls. Stage up f/ 4 bpm w/ 360 psi to 7 bpm w/ 610 psi. 17:00 19:30 2.50 9,555 11,670 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 9555' to 11670' (275 jts in the hole). PU wt 275k, SO wt 157k. Obtain PU & SO wt's per rig engineer. 19:30 21:30 2.00 11,670 11,670 INTRMI CASING CIRC P Circulate 1.5 bottom's up, 670 bbls. Stage up f/ 4 bpm w/ 380 psi to 7 bpm w/ 620 psi. 21:30 00:00 2.50 11,670 13,585 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 11670' to 13585' (320 jts in the hole). PU wt 315k, SO wt 160k. Obtain PU & SO wt's per rig engineer. 02/23/2010 CBU X 1.5 - Continue to Run Casing t/ 15,495' MD - CBU X 1.5 - Continue to Run Casing t/ 17,845' MD - M/U Hanger and Land Casing w/ Shoe @ 17,888' MD - R/U Cement Head - Circ & Condition Mud Prior to First Stage Cement - Cement First Stage w/ 152.2 Bbl of 15.8 PPG Class G Cement - Test Floats (GooD) - Open HES Stage Collar - Cement 2nd Stage w/ 62.2 Bbl of 15.8 PPG Class G Cement - Close Collar and Verify Closure - R/D Casing Running and Cementing Equipment - Set Packoff and Test t/ 5,000 Psi f/ 10 Minutes - Change 7 5/8" Rams to 3 1/2" by 6" Variable Rams , Page 22 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 13,585 13,585 INTRM1 CASING CIRC P Circulate 1.5+ bottom's up, 810 bbls. Stage up f/ 2 bpm w/ 400 psi, 4 bpm w/ 430 psi to 7 bpm w/ 680 psi, 26% Totco flow out going down. After Circulating: Down wt 165k w/ pump, 163k w/o pump. PU wt 290K 02:15 04:30 2.25 13,585 15,495 INTRMI CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 13585' to 15495' (365 jts in the hole). Obtain PU & SO wt's per rig engineer. 04:30 07:00 2.50 15,495 15,495 INTRMI CASING CIRC P Circulate 1.5 bottom's up, 890 bbls. Stage up f/ 2 bpm w/ 430 psi to 7 bpm w/ 700 psi. 07:00 10:00 3.00 154,958 17,888 INTRM1 CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 15495' to 17845' (420 jts in the hole). Obtain PU & SO wt's per rig engineer. Make up FMC 7 -5/8" casing hanger w/ landing joint. RIH and land on hanger w/ shoe @ 17888.31' Final P/U 385, S/O 160 10:00 10:30 0.50 17,888 17,888 INTRM1 CEMEN RURD P L/D Franks Fill -Up Tool - Blow Down the Top Drive & M/U the Cement Head 10:30 13:30 3.00 17,888 17,888 INTRMI CEMEN" CIRC P Circ & Condition Mud Prior to First Stage Cement - ICP 320 Psi @ 1 BPM FCP 730 Psi @ 7 BPM 13:30 13:45 0.25 17,888 17,888 INTRMI CEMEN" SFTY P PJSM on Cementing 7 5/8" Casing 13:45 17:15 3.50 17,888 17,888 INTRM1 CEMEN' CMNT P Cement Casing Shoe w/ Dowell Unit as Follows: Pump 5 Bbl CW 100 - Pressure Test Lines t/ 3700 Psi - Pump 35 Bbl CW 100, 40 Bbl 11.5 PPG Mud Push 11, Drop Bottom ,Plug, 152 Bbl 15.8 PPG Cemmems Drop Closing Plug, Pump 20 Bbl Water, then Displace Cement w/ Rig Pumps - Bump Plugs @ 795.6 Bbl of Mud Pumped - Pressure Up and Hold 1090 Psi f/ 5 Minutes - Check Floats (Good) - Load Stage Collar Closing Plug in CMT Head - CIP 1705 hrs 17:15 18:45 1.50 17,888 17,888 INTRMI CEMEN' CIRC P Pressure Casing Up t/ 3400 Psi to Open HES Stage Collar w/ Rig Pumps 18:45 19:00 0.25 17,888 17,888 INTRMI CEMEN" SFTY P PJSM on Second Stage Cement Job 19:00 20:45 1.75 17,888 17,888 INTRMI CEMEN" CMNT P Perform Second Stage Cement Job as Follows: Pump 30 Bbl CW 100, 30 Bbl 11.5 PPG Mud Push II & 62.1 Bbl 15.8 PPG Cement, Drop Closing Plug, Pump 20 Bbls Water the Displaced Cement w/ 383.4 Bbl 9.9 PPG Mud - Closing Plug on Seat - Pressure Up t/ 1600 Psi - Bled Off Trapped Pressure & Confirmed Stage Collar is Closed - CIP @ 2027 Hrs Page 23 of 33 1 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:00 1.25 17,888 17,888 INTRM1 CEMEN" RURD P Blow Down Lines - R/D Cement Head - UD 7 5/8" Landing Jt, Cement Head, Long Bales & Casing Elevators 22:00 22:30 0.50 17,888 17,888 INTRM1 WHDBO SEQP P Pull Wear Ring - Install 7 5/8" Casing • r • Pack Off 22:30 22:45 0.25 17,888 17,888 INTRM1 WHDBO PRTS P Test Pack Off t/ 5,000 Psi f/ 10 Minutes 22:45 23:15 0.50 17,888 17,888 INTRMI DRILL OTHR P Clean & Clear Rig Floor- Clean out Drip Pan Under Rotary 23:15 23:30 0.25 17,888 17,888 INTRM1 WHDBO SFTY P PJSM on Changing 7 5/8" Rams t/ 3 1/2 X 6 Inch Variable Rams 23:30 00:00 0.50 17,888 17,888 INTRM1 WHDBO SEQP P Remove 7 5/8" Rams 02/24/2010 Change Upper Rams to 3 1/2" by 6" Variable Rams - Test Upper Rams U 250/3500 Psi f/ 5 Minutes - UD 5" DP via the Mouse Hole 00:00 01:45 1.75 17,888 17,888 INTRMI WHDBO SEQP P Continue to Change Out Upper Rams f/ 7 5/8" to 3 1/2" by 6" Variable Rams 01:45 02:15 0.50 17,888 17,888 INTRM1 WHDBO BOPE P Test Upper Rams t/ 250/3500 Psi 02:15 03:15 1.00 17,888 17,888 INTRMI DRILL PULD P Install Bales & DP Elevators 03:15 03:30 0.25 17,888 17,888 INTRM1 DRILL SFTY P PJSM on UD 5" DP via the Mouse Hole 03:30 12:00 8.50 17,888 17,888 INTRM1 DRILL PULD P L/D 5" DP via the Mouse Hole 12:00 00:00 12.00 17,888 17,888 INTRM1 DRILL PULD P UD 5" DP via the Mouse Hole 02/25/2010 P/U and Stand back 90 Stands of 4' DP - Conduct BOPE Test w/ 3 1/2 ", 4" and 4 1/2" Test Jts ( AOGCC, Inspector John Crisp Witnessed the Test) - P/U BHA #3 and 10 Stands of 4" DP t/ 1,289' MD 00:00 09:00 9.00 17,888 17,888 INTRMI DRILL PULD P P/U and Stand Back 90 Stands of 4" XT -39 DP 09:00 17:45 8.75 17,888 17,888 INTRM1 WHDBO BOPE P Test Annular Preventer w/ 3 1/2 ", 4" & 4 1/2" Test Joints t/ 250/2500 Psi - Test Choke Manifold Valves 1 -16, Upper Rams & Lower Rams w/ All Three Test Joints t/ 250/3500 Psi - Test Man /Auto IBOP, 4" Demco, Choke & Kill HCR and Manuals, Blind Rams, Dart & TIW t/ 250/3500 Psi - Perform Koomey Test - BOPE Test Witnessed by AOGCC Inspector John Crisp Note: Test Delayed 1 Day Beyond Normal Cycle per AOGCC Inspector Request; Originally Due 2/24/10 17:45 18:15 0.50 17,888 17,888 INTRMI WHDBO SEQP P Set Bowl Protector in Well Head 18:15 18:45 0.50 17,888 17,888 INTRM1 RIGMN1 SVRG P Service Rig - Addd Spacers to Top Drive Grab Heads 18:45 19:15 0.50 0 33 INTRM1 DRILL PULD P P/U BHA #3 as Follows: 6 3/4" Bit, 5" Motor Page 24 of 33 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 20:30 1.25 33 0 INTRM1 DRILL PULD T Found 7/8" Internal Wrenching Plug & What Appears to be a Cap in the Top of the Motor After Removing the Lift Sub - Break Bit, UD Motor and P/U Back Up Motor - Remove Bend on Housing 20:30 22:30 2.00 0 344 INTRMI DRILL PULD P Continue to P/U BHA #3 as Follows: Float Sub, BAT Tool, 3 X 4 3/4" NMFDC's, XO, Jars, 5 X 4" HWDP t/ 344' MD 22:30 00:00 1.50 344 1,289 INTRM1 DRILL TRIP P RIH w/ BHA #3 w/ on 4" DP f/ the Shed (30 Jts) t/ 1,289' MD 02/26/2010 Continue to RIH t/ 8,633' MD w/ Singles f/ the Pipe Shed - Pressure Test Casing Above HES Stage Collar t/ 1,000 Psi f/ 10 Minutes - Drill Out HES Stage Collar t/ 9,015' MD - CBU - Test Casing t/ 3,500 Psi f/ 30 Minutes - Continue to RIH w/ Singles t/ 16,741' MD - Slip /Cut 120' of Drill Line - RIH t/ 17,720' MD w/ Stands f/ the Derrick 00:00 07:15 7.25 1,289 8,633 INTRMI DRILL TRIP P Continue to RIH w/ BHA #3 on 4" DP t/ 8,633' MD (77 Stands) Filling Pipe and Taking Torque & Drag Readings Every 20 Stands 07:15 08:00 0.75 8,633 8,633 INTRM1 DRILL PRTS P R/U and Pressure Test Casing Above HES Stage Collar t/ 1,000 Psi f/ 10 Minutes 08:00 10:15 2.25 8,633 9,015 INTRM1 DRILL WASH P Wash f/ 8,633' to Stage Collar at 8,776' MD (DPM) - Tagged Cement Stringers at 8,742' MD - Drilled Out Stage Collar & Wash Down to 9,015' MD w/ 4 Stands f/ the Derrick- 300 GPM @ 2300 Psi, 60 RPM 10:15 11:00 0.75 9,015 9,015 INTRM1 DRILL CIRC P CBU @ 300 GPM w/ 2350 Psi and 60 RPM 11:00 12:30 1.50 9,015 9,015 INTRM1 DRILL PRTS P Test Casing t/ 3500 Psi f/ 30 Minutes 12:30 21:15 8.75 9,015 16,741 INTRMI DRILL PULD P S/B 4 Stands and Continue to RIH w/ BHA #3 on Singles f/ the Shed t/ 16,741' MD while Filling Pipe and Taking Torque & Drag Data eI 20 Stands (95 Stands) 21:15 22:30 1.25 16,741 16,741 INTRM1 RIGMNT SLPC P Slip & Cut 120' of Drilling Line - Service Top Drive 22:30 00:00 1.50 16,741 17,720 INTRM1 DRILL WASH P RIH w/ Stands f/ the Derrick t/ 17,503' MD - Wash t/ 17,720' MD; 50 RPM, 210 GPM @ 2100 Psi, Torque 16,500 02/27/2010 Continue to Wash f/ 17,720' - 17,739' MD - Drill Baffle Collar, Float Collar and Shoe Track t/ 17,876' MD - CBU - Log Cement w/ BAT Tool f/ 17,876' - 16,535' MD - POOH t/ 344' MD - Download BAT Data and UD BHA #3 - P/U BHA #4 - Troubleshoot MWD Detection Problems 00:00 02:15 2.25 17,720 17,876 INTRM1 DRILL WASH P Continue to Wash f/ 17,720 - 17,739 MD (Tagged Cement) - Drilled Baffle, Float Collar, and Shoe Track t/ 17,876' MD - 270 GPM @ 2970 Psi w/ 50 RPM 02:15 04:00 1.75 17,876 17,876 INTRM1 DRILL CIRC P CBU 04:00 09:30 5.50 17,876 16,535 INTRM1 DRILL DLOG P Blow Down Top Drive & Log Cement w/ BAT f/ 17,876' MD (Bit Depth) to 16,535' MD Page 25 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 16:15 6.75 16,535 344 INTRM1 DRILL TRIP P POOH f/ 16,535' - 344' MD 16:15 18:00 1.75 344 0 INTRM1 DRILL PULD P S/B HWDP, Download BAT Data and UD BHA #3 18:00 21:00 3.00 0 295 INTRMI DRILL PULD P P/U BHA #4t/ 295' MD - Upload MWD Tools 21:00 00:00 3.00 295 295 INTRM1 DRILL DHEQ T Troubleshoot MWD Detection Problems - Initially Detection was Good but After Sending Downlink Command to the Geo Pilot Pulses Became Irregular - Switched Mud Pumps (No Fix) - Added More Volume & De -Foam to Drill Out Mud - Cleaned Pump Screens 02/28/2010 Shallow Test MWD Tools - RIH w/ BHA #4 t/ 17,833' MD - Displace t/ 9.0 PPG FLo -Thru Mud - Clean Hole ECD was 9.8 PPG - Drill Remaining Shoe Track, Float Shoe and Rat Hole + 20' t/ 17,920' MD - Conduct FIT t/ 12.6 PPG EMW - DrjJIf /17.920' - 18.410' MD 00:00 00:30 0.50 295 295 INTRMI DRILL DHEQ P Shallow Test MWD Tools (Good) 00:30 09:30 9.00 295 17,833 INTRM1 DRILL TRIP P RIH w/ BHA #4 t/ 17,833 (180 Stands) Filling Pipe Every 20 Stands 09:30 09:45 0.25 17,833 17,876 INTRM1 DRILL WASH P Break In Geo -Pilot Seals - Wash Down t/ 17,876' MD; 230 GPM @ 2370 Psi & 30 RPM 09:45 12:00 2.25 17,876 17,876 INTRMI DRILL CIRC P Displace 9.9 PPG LSND w/ 9.0 PPG Flo -Thru - 280 GPM @ 2500 Psi @ 60 RPM - Clean Hole ECD 9.8 PPGE 12:00 13:00 1.00 17,876 17,900 INTRMI CEMEN" DRLG P Drill Reamining Shoe Track, Float Shoe and Rat Hole t/ 17,900' MD - 280 GPM @ 2260 Psi & 90 RPM 13:00 13:45 0.75 17,900 17,920 INTRMI DRILL DDRL P Drill 20' New Hole t/ 17,920' MD (7077' TVD) ADT= 0.36 13:45 15:00 1.25 17,920 17,920 INTRM1 DRILL CIRC P Circ & Condition Mud for FIT - 280 GPM @ 2300 Psi & 110 RPM 15:00 15:45 0.75 17,920 17,920 INTRMI DRILL FIT P R/U and Perform FIT t/ 12.6 PPG EMW 15:45 00:00 8.25 17,920 18,410 PROD1 DRILL DDRL P Drill 3/4" Hole w/ 5200 Geo -Pilot t/ 18,410' MD ADT 5.37 P/U 230, S/O 145, Rot 183 290 GPM @ 2600 Psi / ECD = 10.1 Torque On /Off 13/11.5 @ 110 RPM 03/01/2010 Drilled f/ 18,410' - 20.025' MD. Pumped 35 Bbl, 28 PPB, LCM Pill @ 19,929' MD for Losses - Completed 275 Bbl Whole Mud Dillutions @ 18,691', 19,263' & 19,950' MD to Maintain Rheology Mud Lost to Hole 142 Bbls; Total 142 Bbls Page 26 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 18,410 19,230 PROD1 DRILL DDRL P Drilled 6 3/4" Hole f/ 18,410' - 19,230' MD; Pumped 275 Bbl Whole Mud Dillutions @ 18,691' & 19,263' MD ADT 9.12 P/U 243, S/O 140, Rot 190 Torque On /Off 14,000/12,000 @ 120 RPM 280 GPM @ 2950 Psi / ECD 10.47 WOB 7 -10 12:00 00:00 12.00 19,230 20,025 PROD1 DRILL DDRL P Drilled 6 3/4" Hole f/ 19,230' - 2,0025' MD; Pumped 35 Bbl, 28 PPB, LCM Pill @ 19,926' MD & 275 Bbl Whole Mud Dillution @ 19,950' MD - Loss Rate 20 BPH ADT 9.01 P/U 235, S/O 137, Rot 183 Torque On /Off 12,500/11,500 @ 120 RPM 280 GPM @ 2970 Psi / ECD 10.55 WOB 7 -12 03/02/2010 Drilled f/ 20,025' - 20,341' MD - Circulate While Waiting on Orders from Geology Team - Continued to Drill f/ 20,341' - 21,469' MD - Pump 35 Bbl, 32 PPB, LCM Pills © 20,215, 20,979, 21,170, 21,265 & 21,361' MD - Completed 275 Bbl Whole Mud Dilutions @ 20,200, 20,597' and 20,930' MD 24 Hr Mud Lost to Hole - 871 Bbls; Total Mud Lost to Hole 1,013' Bbls 00:00 05:00 5.00 20,025 20,341 PROD1 DRILL DDRL P Drilled f/ 20,025' - 20,341' MD; Pump 35 Bbl, 32 PPB, LCM Pill @ 20,215' MD; Pump 275 Bbl Whole Mud Dilution @ 20,200' MD ADT 3.56 P/U 235, S/O 135, Rot 180 Torque On /Off 14/11.5 @ 120 RPM 280 GPM @ 3200 Psi; ECD - 10.46 WOB 8 -13 05:00 06:45 1.75 20,341 20,341 PROD1 DRILL CIRC T Rack Back 1 Stand & Circulate While Waiting on Orders Due to Geological Uncertainty - Drilled Across a Fault and Unsure Whether to Go Up or Down - Confer w/ Town Based Geology Team 06:45 12:00 5.25 20,341 20,676 PROD1 DRILL DDRL P Drilled f/ 20,341' - 20,676' MD; Pump 275 Bbl Whole Mud Dilution @ 20,597' MD - Mud Lost for Tour 308 Bbls ADT 3.53 P/U 240, S/O 130, Rot 183 Torque On /Off 14.5/11.5 280 GPM @ 3220 Psi; ECD 10.6 WOB 7 -12 Page 27 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 20,676 21,469 PROD1 DRILL DDRL P Drilled f/ 20,676' - 21,469' MD; Pumped 35 Bbl, 32 PPB, LCM Pills @ 20,979', 21,170', 21,265' & 21,361' MD - Pumped 275 Bbl Whole Mud Dilution @ 20,930' MD - Mud Loss for Tour 563 Bbls ADT 8.91 P/U 250, S/O 125, Rot 185 Torque On /Off 14.5/12.5 280 GPM @ 3040 Psi; ECD 10.6 WOB 5 -10 03/03/2010 Drilled f/ 21,469' - 22,112' MD; Loss Rate Increased t/ 159 BPH, Slowed Pumps t/ 4 BPM and Circulated a 35 bbl, 20 PPB, LCM Pill - Continued Drilling f/ 22,112' - 22,758' MD; Complete 275 Bbl Whole Mud Dilutions © 21,470', 21,755', 22,027', 22,290' and 22,502' MD - Pumped 20 bbl, 30 PPB LCM Pill at the Top of Each Stand 24 Hr Mud Lost to Hole - 1458 Bbls; Total Mud Lost to Hole 2471 Bbls 00:00 10:45 10.75 21,469 22,112 PROD1 DRILL DDRL P Drill f/ 21,469' - 22,112' MD; Completed 275 Bbl Whole Mud Dilutions @ 21,470', 21,755' and 22,027' MD - Pumped 20 bbl, 30 PPB, LCM Pills at the Top of Every Stand ADT 8.18 P/U 250, S/O 184, Rot 115 225 GPM @ 2330 Psi; ECD 10.34 Torque On /Off 15/13 @ 120 RPM WOB 5 -11 10:45 11:15 0.50 22,112 22,112 PROD1 DRILL CIRC T Loss Rate increased to 158 BPH - Slowed Pumps t/ 4 BPM and Circulated 35 Bbl, 20 PPB, LCM Pill while Rotating 120 RPM Mud Lost to Hole for Tour 718 Bbls 11:15 00:00 12.75 22,112 22,758 PROD1 DRILL DDRL P Drill f/ 22,112' - 22,758' MD; Completed 275 Bbl Whole Mud Dilutions @ 22,290' and 22,502' MD - Pumped 20 Bbl, 30 PPB, LCM Pills at the Top of Each Stand ADT 8.78 WOB 5 -11 P/U 252, S/O 122, Rot 178 225 GPM @ 2520 Psi; ECD 10.55 Torque On /Off 15/13.5 @ 120 RPM Mud Lost to Hole 740 Bbls 03/04/2010 _ Continued Drilling f/ 22,758' - 23,927' MD; Drilled Through LCU @y352' MD, Consulted w/ Town Geologist and Decisded to Keep Drilling; Completed 275 bbl Whole Mud Dilutions @ 22,270', 22,974', 23,345' and 23,565' MD; Pumped 20 Bbl, 30 PPB, LCM Pill at the Top of Each Stand 24 Hr Mud Lost to Hole - 1378 Bbls; Total Mud Lost to Hole 3849 Bbls Page 28 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 22,758 23,389 PROD1 DRILL DDRL P Drilled f/ 22,758' - 23,389' MD; Pumped 275 Bbl Whole Mud Dilutions @ 22,974' and 23,345' MD - Pumped 20 Bbl, 30 PPB, LCM Pill at the Top of Each Stand ADT 8.51 WOB 5 -11 P/U 254, S/O 115, Rot 182 225 GPM @ 2500 Psi; ECD = 10.63 Torque On /Off 16/14 @ 120 RPM Losses for Tour - 725 Bbls 12:00 00:00 12.00 23,389 23,927 PROD1 DRILL DDRL P Drilled f/ 23,389' - 23,927' MD; Drilled Through the LCU © 28,352' MD, COnsulted Town Geologist - Continue Drilling While Turning Geo -Pilot Angle Down; Completed 275 Bbl Whole Mud Dilution at 23,905' MD and Added 200 Bbls of Used Mud @ 23,565' MD - Pumped 20 Bbl, 30 PPB, LCM Pill at the Top of Each Stand ADT 10.16 WOB 5 -15 Torque On /Off 15.5/14 @ 120 RPM P/U 255, S/O 110, Rot 178 225 GPM @ 2550 Psi; ECD 10.6 Losses for Tour 653 Bbl 03/05/2010 Continue to Drill f/ 23,927 - 23,891' MD (TD) - CBU while Standing Back 2 Stands - OWFF (Breathing) - BROOH t/ 17,884' MD (Casing Shoe) - OWFF (Breathing) - BROOH t/ 16,881' MD - Displace Wellbore f/ 9.0 PPG Flo -Thru to 9.2 PPG KCL Brine; OWFF (Static); R/D Geo -Span & R/U to Slip & Cut Drill Line, Monitoring the Well on the Trip Tank (5 BPH Static Loss Rate) (� 24 Hr Mud Lost to Hole - 650 Bbls; Total Mud Lost to Hole 4499 Bbls l/ 00:00 05:00 5.00 23,927 23,981 PROD1 DRILL DDRL P Drill f/ 23,927' - 23,981' MD (TD) 7003' TVD; Pumped 20 Bbl, 30 PPB, LCM Pill at the Top of Each Stand ADT 4.49 P/U 255, S/O 110, Rot 179 Torque On /Off 16/14 @ 120 RPM WOB 8 -12 225 GPM @ 3080 Psi; ECD 10.49 05:00 07:30 2.50 23,981 23,842 PROD1 DRILL CIRC P CBU @ 225 GPM 2580 Psi and 120 RPM - Stand Back 2 Stands t/ 23,842 Lost 402 Bbls of Mud while Drilling and Circulating 07:30 07:45 0.25 23,842 23,842 PROD1 DRILL OWFF P OWFF (Breathing) - Flow Noticeably Decreasing Page 29 of 33 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 19:30 11.75 23,842 17,884 PROD1 DRILL REAM P BROOH f/ 23,842' - 17,884' MD; 190 GPM @ 120 RPM; Tight Spots @ 20,558' & 20,280' MD; Checked for Flow @ 22,601', 19,643' and 19,072', Breathing Each Time Lost 242 Bbls of Mud to the Hole During Back Reaming 19:30 20:00 0.50 17,884 17,884 PROD1 DRILL OWFF P Blow Down the Top Drive & OWFF (Breathing) - Flow Slowed to a "Trickle" in 20 Minutes 20:00 20:30 0.50 17,884 16,881 PROD1 DRILL REAM P Continue to BROOH f/ 17,884' - 16,881 - 190 GPM @ 50 RPM 20:30 23:15 2.75 16,881 16,881 PROD1 DRILL CIRC P Displace Wellbore Fluids Above 16,881' MD f/ 9.0 PPG Flo -Thru to 9.2 PPG KCL as Follows: Pumped 40 Bbl Viscosified 9.0 PPG Flo -Thru Spacer, 200 Bbl 9.0 PPG Flo -Thru, 40 Bbl Viscosified 9.2 PPG KCL Spacer and 300 Bbls of 9.2 PPG KCL Brine 23:15 00:00 0.75 16,881 16,881 PROD1 RIGMNI SLPC P OWFF (Static) - Blow Dow the Top Drive & Geo -Span - R/U to Slip & Cut Drill Line - Monitor Well on the Trip Tank (Static Loss Rate 5 BPH) 03/06/2010 Slip & Cut 60' of Drill Line - POOH, Stand Back HWDP „Download MWD and UD BHA #4 - R/U and Run Liner on 4” DP t/ 17,881' MD 24 Hr Mud Lost to Hole - 119 Bbls; Total Mud Lost to Hole 4618 Bbls 00:00 00:15 0.25 16,881 16,881 PROD1 DRILL OWFF P OWFF (Static) 00:15 00:30 0.25 16,881 16,881 PROD1 RIGMNT SFTY P PJSM on Slip & Cut Drill Line 00:30 01:45 1.25 16,881 16,881 PROD1 RIGMNT SLPC P Slip & Cut 60' Drill Line - Service Top Drive 01:45 08:30 6.75 16,881 389 PROD1 DRILL TRIP P POOH on Elevators - Hole Fill 49.5 Bbls Over Calculated 08:30 12:00 3.50 389 0 PROD1 DRILL PULD P Stand Back HWDP - L/D the Bumper Sub - Read MWD Data - UD the Remainder of BHA #4 Static Loss Rate 8 BPH 12:00 12:30 0.50 0 0 COMPZ CASING RURD P R/U to Run Liner 12:30 15:15 2.75 0 3,583 COMPZ CASING RUNL P ,Run 4 1/2" Slotted /Blank Liner per Detail t/ 3545' MD - MU Baker Flexlock "DG" liner hanger assembly. 15:15 15:45 0.50 3,583 3,583 COMPZ CASING OTHR P Mix & Apply Pal -Mix and Allow to Cure 15:45 00:00 8.25 3,583 17,881 COMPZ CASING RUNL P Run Liner on 4" DP t/ 17,881' MD - P/U 235, S/O 135, Rot 175 (Obtained Rotating Data at Stands 1,50, 100 &150) Pipe displacement 49 Bbls under Calculated for Liner Run Page 30 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/07/2010 24 hr Summary Continue to Run Liner on 4" DP t/ 21,000' MD - Drop Ball, Set & Release from Hanger - OWFF - Circ & Condition Mud Due to U- Tubing (Flowing From Drill Pipe) - POOH t/ 2576' MD - Slip & Cut 60' of Drill Line - POOH & UD Liner Running Tools - R/U and Run 3 1/2" Completion String t/ 9,073' MD 24 Hr Mud Lost to Hole - 156 Bbls; Total Mud Lost to Hole 4774Bb1s 00:00 02:00 2.00 17,881 21,000 COMPZ CASING RUNL P Continue to Run Liner on 4" DP t/ 21,000' MD - P/U 250, S/O 125 02:00 03:30 1.50 21,000 17,425 COMPZ CASING RUNL P Hang Off Liner as Follows: Pump 6 Bbls @ 3 BPM, Drop 29/32" Ball, Circ Ball Down Initially © 4 BPM w/ 750 Psi, at 100 Bbls Reduced Rate t/ 2 BPM @ 250 Psi - Ball on Seat @ 154 bbls Pumped (1541 Strokes) w/ 800 Psi - Pressure up t/ 2400 Psi - Slack Off t/ 125K Liner Hanger Not Set - P/U t/ 250K and Mark - Pressure Up t/ 2500 Psi - Slack Off t/ Block Weight + 10K = 65K; Hanger Set - Pressure Up t/ 3400 Psi t/ Release HR - Bleed Pressure t/ 0 - P/U t/ Verify Weight Decreased - Pressure Up t/ 3750 Psi; Ball Seat Sheared - Pump 1/2 BPM While Picking Up to Clear Liner Running Tools f/ Hanger & HR Sleeve rti. Z31 1t �' Liner Tail @ 21,000' MD - Top of ? Liner @ 14,425' MD 03:30 04:15 0.75 17,425 17,425 COMPZ CASING CIRC P Break Out Top Drive and OWFF - Circ & Cond Mud to Prevent U- Tubing Up Drill Pipe While Tripping - 5 BPM @ 800 Psi (123 bbls) - Blow Down Top Drive - OWFF (Static) 04:15 10:00 5.75 17,425 2,576 COMPZ DRILL TRIP P POOH on Elevators f/ 17,425' t/ 2,576'. P/U = 105, S/O = 100. Hole fill 45 bbls over calculated volume. 10:00 11:30 1.50 2,576 2,576 COMPZ RIGMNT SLPC P PJSM - Slip & Cut 60' of Drill Line. Service Top Drive & Drawworks. Static losses averaging 8 bbl /hr. 11:30 12:15 0.75 2,576 0 COMPZ RPCOM PULL P Continue to POOH on Elevators f/ 2,576' t/ 55'. PUW = 95, SOW = 90. Hole fill 5 bbl over calculated fill. 12:15 12:45 0.50 0 0 COMPZ RPCOM TRIP P UD Liner running tools & Clean Floor. 12:45 13:45 1.00 0 0 COMPZ DRILL RURD P Pull drilling wear bushing and install Completion wear bushing - Rig Up to Run 3.5" Tubing. 13:45 14:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM prior to RIH w/ 3.5" Tubing. 14:00 00:00 10.00 0 9,073 COMPZ RPCOM RCST P RIH w/ 3 1/2" EUE Upper Completion per Detail t/ 9,073' MD (284 Joints + WLEG, "XN" Nipple, Packer & 2 -G LM's) P/U 115, S/O 95 Page 31 of 33 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/08/2010 24 hr Summary Continue to Run Completion String t/ 13,781' MD - P/U and M/U SSSV and Control Line; Test Same U 6500 Psi f/ 5 Minutes - Continue to Run Completion String U 15,961' MD - P/U Tubing Hanger, Land Tubing in Spool and Test Hanger Seals t/ 5,000 Psi (Good) - Set TWC, N/D BOPE and N/U Tree - Test Tree t/ 5,000 Psi f/ 10 Minutes (Good) - R/U and Displace Wellbore Fluids w/ 485 Bbls of Inhibited 9.2 PPG KCL Brine and 220 Bbls of Diesel; SITP After Displacement 800 Psi - Drop Ball & Rod and Set Packer w/ 3950 Psi 24 Hr Mud /Brine Lost to Hole - 132 Bbls; Total Mud /Brine Lost to Hole 4906 Bbls 00:00 04:45 4.75 9,073 13,781 COMPZ RPCOM RCST P Continue to Run Completion Tubing t/ 13,782' MD (149 Jts + GLM w/ SOV) P/U 133, S/O 99 04:45 06:15 1.50 13,781 13,806 COMPZ RPCOM PULD P PJSM - P/U Control Line Spool and Tubing Hanger - M/U SSSV and Control Line - Test Control Line t/ 6500 Psi f/ 5 Minutes 06:15 09:45 3.50 13,806 15,961 COMPZ RPCOM RCST P Continue to Run Completion Tubing t/ 15,961' MD (64 Jts) - P/U XO, 4 1/2" IBT Space Out Pup and 2 Jts of Tubing - P/U 150, S/O 102 09:45 10:30 0.75 15,961 15,961 COMPZ RPCOM PULD P PJSM - P/U Landing Jt B and Pull Wear Ring - UD Wear Ring and Landing Jt B 10:30 12:00 1.50 15,961 15,996 COMPZ RPCOM HOSO P M/U Tubing Hanger and Pull Control Line Though Orifice - Test U 5200 Psi (Good) - Drain the Stack, Blow Down Lines and Land Tubing w/ Tail @ 15,996' MD 12:00 12:45 0.75 15,996 15,996 COMPZ RPCOM PRTS P RILDS and Test Hanger Seals t/ 5,000 Psi f/ 5 Minutes - Set TWC 12:45 13:15 0.50 15,996 15,996 COMPZ DRILL OTHR P Clean & Clear Rig Floor - Change Saver Sub 13:15 16:00 2.75 15,996 15,996 COMPZ WHDBO NUND P N/D Riser and BOPE Stack - N/U Tree 16:00 16:30 0.50 15,996 15,996 COMPZ WHDBO PRTS P Pressrue Test Tree t/ 5,000 Psi f/ 10 Minutes - Pull TWC 16:30 22:45 6.25 15,996 15,996 COMPZ DRILL CIRC P R/U Hard Lines & Displacement Manifold - Test Lines t/ 3,000 Psi - Displace Wellbore Fluids as Follows: Pumped 40 Bbls 9.2 PPG KCL Brine, 485 Bbls 9.2 PPG Inhibited KCL Brine and 220 Bbls Diesel - SITP After Displacement 800 Psi 22:45 23:30 0.75 15,996 15,996 COMPZ DRILL OTHR P R/U Lubricator & 1- 5/16" Drop Ball and Rod - R/D Lubricator & R/U Hard Line 23:30 00:00 0.50 15,996 15,996 COMPZ DRILL PACK P Pressure Test Lines t/ 4200 Psi - Pressure Up t/ 3950 Psi t/ Set Packer Page 32 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/09/2010 24 hr Summary Pressure tested tubing to 3949 psi, bled to 3685 psi in 30 minutes - bled off tubing to 2200 psi - Pressure tested 7 5/8" x 3 1/2" annulus to 3566 psi, bled to 3474 psi in 30 minutes. Bled off tubing, sheared DCK -2 valve in upper GLM. Shut in tubing with 800 psi SITP - bled annulus to zero and shut in annulus. Blow down lines - RD hard lines, hoses and manifold. PJSM - Install FMC lubricator and test to 1000 psi - set BPV - remove lubricator to rig floor - install required gauges and secure wellhead. PJSM on laying down drill pipe. Lay down drill pipe from derrick for rig move - 510 joints (170 stands) of 4" drill pipe. Blow down steam and water. Disconnect service lines. Off of hi -line at 2100 hrs 3 -9 -2010 hrs. Note: Rig released for move from CD3 -124 to CD3 -121 @ 2100 hrs 3 -9 -2010. Note: Final Tubing press 750psi, IA 450 psi, OA 300 psi. 00:00 01:30 1.50 15,996 0 COMPZ DRILL PRTS P Pressure tested tubing to 3949 psi, bled to 3685 psi in 30 minutes - bled off tubing to 2200 psi - Pressure tested 7 5/8" x 3 1/2" annulus to 3566 psi, bled to 3474 psi in 30 minutes. Bled off tubing, sheared DCK -2 valve in upper GLM. Shut in tubing with 800 psi SITP - bled annulus to zero and shut in annulus. 01:30 02:00 0.50 0 0 COMPZ DRILL RURD P Blow down lines - RD hard lines, hoses and manifold. 02:00 03:15 1.25 0 0 COMPZ WHDBO SEQP P PJSM - Install FMC lubricator and test to 1000 psi - set BPV - remove lubricator to rig floor - install required gauges and secure wellhead. 03:15 03:30 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down drill pipe. 03:30 20:30 17.00 0 0 COMPZ DRILL PULD P Lay down drill pipe from derrick for rig move - 510 joints (170 stands) of 4" drill pipe. 20:30 21:00 0.50 0 COMPZ DRILL PULD P Blow down steam and water. Disconnect service lines. Off of hi -line at 2100 hrs 3 -9 -2010 hrs. Note: Rig released for move from CD3 -124 to CD3 -121 @ 2100 hrs 3 -9 -2010. Page 33 of 33 • WELL LOG TRANSMITTAL To: State of Alaska March 16, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD3 -124 AK -MW- 0006991484 CD3 -124 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 50- 103 - 20612 -00 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 50 -103- 20612 -00 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50- 103 - 20612 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3536 Fax: 907 - 273 -3535 U D Bryan.Burinda@halliburton.com RECEIVED MAR 2 3 2010 Date: Signed: Page 1 of 1 Schwartz, Guy L (DOA) From: Anderson, Nina M [ Nina .Anderson @conocophillips.com] Sent: Thursday, January 21, 2010 2:50 PM To: Schwartz, Guy L (DOA) Cc: Robertson, Ryan G Subject: RE: CD3 -124 (PTD 210 -008} Guy — Yes we have planned to do a BAT sonic log to evaluate the cement quality. This will most likely be run on our clean out BHA which h ch will drill out the intermediate shoe track. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)- 265 -6403 Cell: (907) 575 -3256 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 19, 2010 1:55 PM To: Anderson, Nina M Subject: CD3 -124 (PTD 210 -008) Nina, One other item in the procedure that I didn't see was a cement quality log on the 7 5/8" casing . You don't list a BAT sonic in the LWD string or mention a USIT (FASTCAST) on eline. You will need something in order to satisfy the UIC requirements for an injector well. Thanks, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/21/2010 • • } SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS < 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION' F• ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Colville River Field, Fiord Oil Pool, CD3 -124 ConocoPhillips Alaska Inc. G 't O Permit No: 210 De6 J` Surface Location: 4007' FNL, 1127' FEL, SEC. 5, T12N, R5E, UM Bottomhole Location: 749' FNL, 4286' FEL, SEC. 2, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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). Sincerely, •/ Daniel T. Seamount, Jr. Chair DATED this 2° day of January, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) ill • ,FWED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4 i,Z , ,Ni 1 .', iJ PERMIT TO DRILL 4ii t -;: v ,, : °.!-. i< i)MMIS'vit. 20 AAC 25.005 ,_ , 1a. Type of Work: 1b. Current Well Class: I Exploratory ❑ Development Oil El lc. Specify if well is proposed for: Drill 0 • Re -drill ❑ Stratigraphic TesLJ Service El • Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone _ Single Zont0 Shale Gas ❑ 2. Operator Name: 5. Bond: D Blanket If Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180. CD3 - 124 • 3. Address: 6. Proposed Depth: 12. Field /PooI(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 24471' • TVD: 6984' • Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 4007 FNL, 1127 FEL, Sec 5, T12N, R5E, UM ADL 372105, 025526, 380092 Fiord Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1314 FNL, 427 FEL, Sec 11, T12N, R4E, UM ALK 380077 2/2/2010 Total Depth: 9. Acres in Property: 14. Distance to k: - Zt£) i F t_ L 11 et ° `' . 749 FNL, 4286 FEL, Sec 2, T12N, R4E, UM 2560 Nearest Property: - 3000' from Fiord PA i 25 1 r /3 -ie> 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: -/f i,(c feet 15. Distance to Nearest Well Open to KB Elevation above GL: 1 fee / Surface: x - 387915.6 y 6003770.1 Zone 4 ,t.. 3 Same Pool: • Nigliq 1 , 2300' @ 21725' MD 16. Deviated wells: Kickoff depth: 400 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.8° d Downhole: 3160 psig • Surface: 2466 psig • 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 • 114 • Pre - installed 13.5" 10.75" 45.5# L -80 BTC -M 3586 37 37 3623 2500 • 636 sx ASL3, 270 sx 15.8 cl G 9.875" 7.625" 29.7# L -80 BTC -M 17395 37 37 17432 6994 • 524 sx 15.8 cl G, 272 sx cl G for K2 6.75" 3.5 9.3# L -80 EUE -M 16410 32 32 16442 6785 Production tubing 4.5 12.6# L -80 SLHT 8029 16432 6782 24461 . 6984 • 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 MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis Q Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program is 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson @ 265 - 6403 t a Printed Name G. L. Alvord Title Alaska Drilling Manager Signature _ /jX /� /J Phone Date / -�I/ - 2 0`0 /147zi; u B , g ethp /fr-Ve11701mission Use Only Permit to Drill API Number: Permit A r al ISee cover letter Number: Z`�• > C -- LJ 50. � Date: / ,// for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: X350 est. 40P (es{`' Samples req'd: Yes ❑ No Er Mud log req'd: Yes ❑ No [ Other: ZSDO f J DI, Aft � I- ( H2$ measures: Yes ❑ No 121' Directional svy req'd: Yes [✓]� No El w4� iuc Z AAc deD3 c� )(Z) l Cc»��. -/ c is d �, L APPROVED BY THE COMMISSION /1� f - `� DATE: " "110." , COMMISSIONER • /// Form 10-401 (Revised 1/2009) n , S�.ibmit in Duplicate ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 January 14 2010 r=) T Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3 -124 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore pre - produced injection well from the CD3 (Fiord) pad. The intended spud date for this well is February 2 "d , 2010. It is intended that Doyon Rig 19 be used to drill the well. CD3 -124 will be completed as a pre - produced horizontal injector in the Nechelik reservoir. The well will be flowed back to mitigate reservoir damage and then hooked up to begin pre - production. Before the well is converted to an injector, a 10 -403 and a cement bond log will be submitted, applying to change the service of the well. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. 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. This will be the 6 winter season of drilling on the Fiord pad and there has not been a significant indication 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 drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. 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: 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. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265 -6403 or Chip Alvord at 265 -6120. Sincerely, Nina Anderson Drilling Engineer • • Attachments cc: CD3 -124 Well File / Sharon Allsup Drake ATO 1530 Ryan Robertson ATO 1702 Mike A. Winfree ATO 1708 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation I � CD3 -124 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13 -1/2" Hole / 10 -3/4" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams. Gas Hydrates Low Monitor well at base of permafrost, increase mud • weight, decrease mud viscosity, increase circulating times, control drilling rates and low mud temperatures. Running Sands and Gravel Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight. Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, thin mud rheology, pump LCM pills and use of low density cement slurries. 9-7/8" Hole / 7 -5/8 es Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight above 9.6 ppg. Flow Surface Formations checks during connections. Mud weight increase if >2000' TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density (ECD). Use of weighted sweeps. Abnormal Reservoir Low - Well control drills. Increase mud weight. Pressure Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. 6 -3/4" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density (ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Perform well control drills. Increase mud weight if needed. Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. ORIGINAL • Riq Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 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 3000 psi. • 7) Drill out 20' of new hole and 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 into the Nechelik reservoir sand (LWD Program: GR/RES /PWD). 10) Run and cement 7 -5/8" casing as per program. Perform a leak off test down the 10 -3/4" x 7 -5/8" casing annulus to confirm the fracture pressure referenced to the surface casing shoe. 11) Freeze protect casing annulus and casing. 12) BOPE test to 3500 psi. 13) Pick up 6 -3/4" directional drilling BHA. 14) Pressure test casing to 3,500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 15) Displace well to Flo -Thru drilling fluid. 16) Drill 6 -3/4" horizontal section to well TD (LWD Program: GR/RES /PWD). 17) Circulate the hole clean and pull out of hole. 18) Run lower completion of 4 -1/2" sloted liner and liner hanger.' 19) Run upper completion: 3 -' /2, 9.3 #, L -80 tubing with SSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. Sting in, space out and land hanger. 20) Install 2 way check and pressure test hanger seals to 5,000 psi. 21) Nipple down BOP. 22) Install tubing head adapter assembly. ,.M. - Fr • 23) Pressure test adapter assembly to 5,000 psi. 24) Remove two way check valve. 25) Circulate tubing to diesel and install freeze protection in the annulus. 26) Drop ball and rod, set packer and test tubing and annulus to 3,500 psi for 30 minutes. 27) Set BPV and secure well. • 28) Move rig off. ORIGINAL • 1 Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3 -318 is the closest existing well. Ellipse to ellipse separation is 57.13' @ • 2,467.07' MD. Drilling Area Risks: There are no high -risk events (e.g. over - pressures zones) anticipated. , Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard . LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. 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 CD3 -124 will be injected into a permitted annulus on CD3 pad or the class 2 /class 1 disposal well on CD1 pad. The CD3 -124 surface /intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2,000' TVD. The significant hydrocarbon zones are the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoirs. There will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Once CD3 -124 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10 -403 would then 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) * (2,500') + 1,500 psi = 3060 psi Pore Pressure = 1,131 psi Therefore Differential = 3060 —1131 = 1929 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 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 P '!GINAL • • DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7- Production Hole 10 -3/4 "surface casin g casing 5/8" casin point — 9 -7/8" Section — 6 -3/4" point — 13-1/2" Density 8.8 — 9.6 ppg 9.6 — 9.8 ppg 9.0 -9.3 ppg , PV 10 -25 10 -15 YP 20 — 60 15 — 25 25 — 30 Funnel Viscosity 100 — 200 Initial Gels 4 — 8 10 — 15 10 minute gels <18 12 - 20 API Filtrate NC —10 cc / 30 min 4 —12 cc /30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc /30 min PH 8.5 — 9.0 9.0 — 10.0 9.0 — 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at ± 300 sec /qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80 -100 sec /qt. Mud weight will be maintained at < 9.6 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo -Thru drill -in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. • Fiord (CD3) Colville River Field CD3 -124 Pre - produced Injector Updated 01/14/10 ■16" Conductor to 114' Sperry Drilling Services CD3- 124wp04 Packer Fluid mix: 0 Inhibited 9.2 - 9.4 DDg KCI Brine with 1500' TVD diesel cap 10 -3/4" 40 ppf L -80 BTC -Mod A Surface Casing @ 3624' MD / 2500' TVD 6 GL J cemented to surface TOC @ +1 7650' Upper Completion MD TVD MD / 3851' TVD Qannik Interval 1) Tubing Hanger 32' 32' Top +/- 8150' MD / 4019' TVD 2) 4 -Y2" 12.6#/ft IBT -Mod Tubing (2 jts), XO 3) 3 -1/2" 9.3 #/ft EUE -Mod Tubing ' 0 0),T 4) Camco TRMAXX -5E SSSV (2.812" ID) 2200' 1919' with control line to surface ES Cementer 5) 3 -'W 9.3 #/ft EUE -Mod Tubing +/- 8709' MD / 6) Camco KBMG GLM w/ DV 6305' 3400' 4206' TVD 7) 3 - %2" 9.3 #/ft EUE -Mod Tubing 8) Camco KBMG GLM w/ DV 12860' 5600' 9) 3 -' /2" 9.3 #/ft EUE -Mod Tubing 10) Camco KBMG GLM (2.867" ID) w /DCK2 shear 15680' 6545' 3 -1/2" 9.3 ppf L -80 EUE M Pinned for 2500 psi casing to tbg shear tubing run with Jet Lube Run'n'Seal 11) 31/2" 9.3#/ft, EUE -M (2) pipe dope 8 GL 12) Baker 3.5" X 7 -5/8" Premier Packer 15760' 6572' 13) 3 -1/4" 9.3#/ft, EUE -M (1) 14) HES "XN" (2.75" min ID) Ca 70.7 15800' 6585' 15) 3 -14" 9.3#/ft, EUE -M 16) 31/2' 9.3 # /ft, EUE -M w/ mule shoe located at 16435' 6783' WLEG sub bottom, +/16442' Lower Completion: Too MD TVD 17) Baker 5 "x7 -5/8" Flexlock Liner Hanger w /setting sleeve 16432 6782' 18) 4- 12.6 # /ft, SLHT Tubing 19) 4-1/2" 12.6 #/ft L -80 SLHT liner with blanks when out of Nechelick sand 20) Orange Peel Shoe with 4-1/2" 12.6# L -80 Box Up 24,460' 6984' 0 TOC Calculated � 4 -Y=" 12.6#/ft SLHT liner: @ +/- 15,460' MD / 6472' TVD 8 slots / ft, 2 - x 1/8" slots (300' above Packer & 500' MD above Kuparuk C) �s 20 Top Kuparuk C 16,819' MD / 6884' TVD " � 0 \\ 18 Top Nechelik 17392' MD / 6989' TVD -- - - - - -� 6 -3/4" Hole 7 -5/8" 26 ppf L -80 BTC Mod TD at 24,471' MD / 6984' TVD • Production Casing @ 17,432' MD / 6994' TVD ORIGINAL • CD3 -124 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (Ibs. / gal) (psi) (psi) 16 114 / 114 • 10.9 52 53 10 -3/4" 3624 / 2500 - 14.5 1131 1635 7 -5/8" 17,432 / 6994 _ 16.0 3164 . 2462 N/A 24,469 / 6984 • 16.0 3160 ' N/A • NOTE: The Doyon 19 5,000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/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 FPP = 0.4535 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) — 0.1] D = [(10.9 x 0.052) — 0.1] x 114 = 53 psi OR ASP = FPP — (0.1 x D) = 1131 — (0.1 x 2500') = 881 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 2500 = 1635 psi OR ASP = FPP — (0.1 x D) = 3165 — (0.1 x 6994') = 2465 psi 3. Drilling below intermediate casing (7 -5/8 ") ASP = FPP — (0.1 x D) = 3160 — (0.1 x 6984') = 2462 psi O R! G !NAL • Cementing Program: 10 -3/4" Surface Casing run to 3624' MD / 2500' TVD. • Cement from 3624' MD to 3124' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3124' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1717' MD). Lead slurry: (3124- 1549') X 0.3638 ft /ft X 1.5 (50% excess) = 859.5 ft below permafrost 1549' X 0.3638 ft /ft X 4 (250% excess) = 1972.1 ft above permafrost Total volume = 859.3 + 1972.1 = 2832 ft => 636 Sx @ 4.45 ft /sk System: 636 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft /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 ft /ft X 1.5 (50% excess) = 272.8 ft annular volume 80' X 0.5397 ft /ft = 43.2 ft shoe joint volume Total volume = 272.8 + 43.2 = 316.0 ft => 270 Sx @ 1.17 ft /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 ft /sk 7 -5/8" Intermediate Casing run to 17,432 MD / 6994' TVD . First Stage: Cement from 17,432' MD to 15,460' MD. (500' of Class G + adds @ 15.8 PPG and minimum 300' MD above the packer). Assume 40% excess annular volume. Lead Slurry: (17,432'- 15,460') X 0.2146 ft /ft X 1.4 (40% excess) = 593 ft annular vol. 80' x 0.2577 ft /ft = 20.6 ft shoe joint volume Total volume = 20 ft + 593 ft = 613 ft => 524 Sx © 1.17 ft /sk System: 524 Sx Class G + 0.2% D046 antifoamer, + 1%S2, 0.2 %D46, 0.3 %D65 accelerator @ 15.8 PPG yielding 1.17 ft /sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +/- 500' above the K2 • interval with Class G + additives © 15.8 ppg. Assume 40% excess annular volume Lead: (8709'- 7650') X 0.2146 ft /ft X 1.4 (40% excess) = 318.2 ft annular vol. Total Volume = 318.2 ft => 272 Sk @ 1.17 ft /sk System: 272 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft /sk 1 By Weight Of mix Water, all other additives are BWOCement 0 • p 71V a lii t i ConocoPhilli s Alaska Inc. r ,' I 'I'I Western North Slope -- � - CD3 Fjord Pad Plan: CD3 -124 fii Plan: CD2 -124 Plan: CD3- 124wp04 Standard Proposal Report F � ' � ' " �I 4 Al i ll '' 'd III I � _4 i " !I��li�l'uii '�" 08 January, 2010 } i [ NAD 2 0 1 I'�I # Large Do NOT print __ 44 v r4 i il 4 HALLIBURTON Sperry Drilling Services *"\Ir"' l: 5 Project: Western North Slope Site. CD3 Fiord Pad CD3- 124wp04 ConocoPhil lips WBII: Plan: CD3 -124 1 131 ° 1 1 1 1 13 1 1 1 1 5 1 ° 1 1 1 1 -4s00 1 Well Plan' CD3 -124 - I 1 1 1 1 Alaska DOI60 -e4: Short wshort, h simple or or ko9er wells with low btumm'N 8816.4 -68. Lo walla w8h relatively profiles DDI = 7 Long 0000 - 9°00 1301> 6 8 Long, Icrluom prorim with a high degree of difficulty 1- IALLIBURTORI REFERENCE INFORMATION - Surface Location - - Coddnate (WE) Reference. We1 Phan' CD3 -124. True Not ° w s """"""""" Vertical (TV()) Reference. Phan: CD3 -124 (363 +12 5) r5/ 48 8011 (Doyen 19) Ground Level - ):D(7 9'"9"'S/ BJ p°ill197g Calcuatian Method Reference. MinimumdCurvature 000E) Latitude 70'25' 8.091N Geodetic Zone: Alaska Zone 4 Longitude 19 °54' S° 502 W - 15 January 07 2010 Geodetic Datum. North American Datum 1983 CASING DETAILS SURVEY PROGRAM A _ 1M1 Start Build 1.50 U0.00 2451 20 3624 44 10.314 10.3 x 13- ae 35.30 1000.00 CO3-124wp04 (Ran: CO2 -124( CB- GYRO-SS GO�> Start Build 2.20 993 Bit 95°0 17431.75 7 - 518 7 - 5/8'X9 - 718' 190.00 24499.51 C33- 124wp04 (Ran: CO2 -124( MWOnFRAKCAZSC 4500- 4.1/2 "x6314" 983 80 6935.00 24469 51 4 -1/2 4-112• x 6-3/4' Start DLS 3.50 TFO 7.60 1 -eb09 >(4 - I CD3.101FWwp)O( T4le Start 12753.42 hold at 2639.59 Mb, 1 1 - eo. a r 1 Name lYDSS ,-s +E/ -w snaps c - 9 - M1� Start 3863.37 hold at 20606.14 MD 1 \ 1 - c- 1o1Fwwl,io( r 93500 3ze0 o4 - te4az 9 Poem `Z' 00 - Start DLS 1.50 TFO 94.52 \ t CD3- 101FWw0101 Top Nec100 8969 -2580 16 - 1463463 Point ' \ te� - 33 l3 Start 1867.41 hold at 18125.96 MD • , - SECTION DETAILS +^ M1 M 100 19314" X 13.1/2" , ,, g III _ Start DLS 2.00 TFO 147.75 _ Sec MO Inc l TVO TVO88 -S ♦FJ-W 0009 TFace 730+ Target ' 1 54".1t 54".1t 0. 0Az.00 36.30 lzso 0. + 00 0,00 ° 00 ono 0.00 0 1 ° - Start Build 1.50 2 399.70 0.00 040 309.70 35090 0.00 000 0.00 000 0.00 Z o- n � (�O -0 3 59.79 340 250.00 500.70 59.90 -1.79 -4 92 1.50 250.00 1 18 = Ov- 4 901.80 0.95 250.00 99.70 09.90 -13.15 -35.16 2 20 0.00 6.68 . 1> - - " $ O 5 2699.99 10.99 25740 218947 2120.67 - 217.20 •198.54 3.50 7.50 95548 - ® sp it - - O O O O _ 6 15993.01 70.39 297.04 5449.70 8400.90 3955.25 -12777.29 0.00 0.00 4472.14 0 � - i r O 7 1911.93 70.95 268.57 5508.80 6540.00 4014.9 -13168.6° 240 80.00 4649.93 N 1 0 16370.47 72.50 277.22 679.00 6715.00 3987.63 -139798 1.50 80.00 4951.78 CD3 101FWwp02 Mid A�p0 / $ % o 0 9 17431 75 83.00 310.00 993.80 6945.00 - 2579.9 - 1530 60 3.17 76.07 5810.08 - - 10 17921.98 90.00 320.91 7023.80 6975.00 3225.38 - 14972.00 2.64 57.70 6285.51 0 O p O I a 11 18055.31 92.00 320.91 702147 972.67 - 2121.91 - 15057.04 1.50 0.00 642108 - 1, e 4 D O m o - 12 19125.96 9090 32155 7019.74 °97094 - 209.81- 1510121 2.00 141.75 6491.34 1:1 O O 0 19 19993.37 90.80 321.65 9993.51 6044.71 502.1° - 19259.39 0.00 0.00 835047 _ 7 X 9.7(8" -3F 1 ' 15 24469.51 00.07 390.83 9 9 64 °380 35.00 3280-15432 9 000 52 9 0.00 1281726 CD3101FWwpp/I2 Toe - 1 - O G O O O _ 14 20605.14 90.07 330.83 5988.80 0940.00 -93.27 -16590 49 1 50 CD3 - 101FWwpXX Top Nechel cr G � , ' -490- 1 - --459 1 ' Start DLS 2.60 TFO 89.00 mervavad 1 Start DLS 1.50 TFO 80.00 -2500 o 2600 5000 ]shoo - 1 Start DLS 3.17 TFO 76.07 - 1 I 1 I 1 I I I 1 I I I I I I I I I I I I � er ' r+ "a - - Start DLS 2.64 TFO 57.70 _ + r ° i Start Build 1.50 _ - _ 5° - - Start Build 2.20 .0000 - • 9 °°° 90 Start DLS 3 50 TFO 7.60 - - 1 I 1 I 1 1 I 1 1 I 1 1 I I I 1 1 1 1 1 48000 - 13500 590 - 4500 0 - Start 12753.42 hold at 2839.59 MD West(- )IFast( +) (4500 ft/In) S - C -30 2s9 --- _ 10 -3/4" x 13 -1/2" • � � 11 -- - - - --- - - - - - . - - - - - - - - -- - - - - - - - ---- 2500 a C-20 V' ANNOTATIONS v _ hit O - TVD 11355 MD Annoi0ton -�1 - 399 70 350 9D 39 70 Stmt Build 1.50 O 599.70 5509D 59979 Stmt Buid 220 _ O 699.70 °5090 9019 Start OLS 350 TFO 700 00 Start DLS 260 TFO 89.00 216947 212067 2999 Stmt 12753 92 hold at 2639.59 MD d - _ K -3 K - Basal O - 644970 6400 90 15393 DI Start DLS 260 TFO 8900 (3 T 1 Start DLS TFO 80.00 _ 6588 80 6540 00 15811 93 Start DLS 150 TFO 80,00 _ TFO - - .. _ __ _ - _ - - # _ ._ - - __ - - - - __ - - - - - _ _ _ - - _ _ 8]63 BO 6715 00 16370 47 Start DLS 3 17 TFO 7807 _ -- - - - -- - -- - - - - eQ - _ Start DLS 3.1 76.Q7 - 993 e° 89450° 1743175 slat DLS 2°4 TF05770 - - - - - - - - - - - � 0 -- _ O 1 -- 1- 7023°0 8975 9 17921 98 Start BuiM 1.9 _(3 / Start DLS 2.64 TFO 57 7021.47 6972.67 18055.31 Start DLS 2. TFO 147.75 _ K -2 Basal K-2 ^O O 1 t I / - .7019 74 6970.94 18125 96 Start 9 t 1867 41 hold at 18125 9 MD p ild 1.50 8993.51 8944 71 19993 37 Stmt DLS 1 5D TFO 94 52 j ^ ^O ■ 1 / 898880 94000 2060614 Start 38°337 hold at 29914 MD H s09- Albion 97 ^ry 1 ' / / / / Start DLS 2 00 TFO 147.75 -5000 6983 Bit 935°0 245951 TD at 2446951 tl 1 / / • Start 1867.41 hold at 18125.96 MD - .rr / - Albion 96 ,�j00 1 z - Start DLS 1.50 TFO 94.52 FORMATION TOP DETAILS - - 1 / Start 3863.37 hold at 20606.14 M D - Top HRZ Base HRZ K -1 Top Kuparuk D 6.0503 M1 NDSaPat6 MDPeth Formation 1 0 518" X 9- 7/B " - � / 24] BO 2428 DD 3555 31 C -30 Top K C ^h9 c:i / • - - 4 -1/2" X B$ /4" - 28533 80 280500 46]°62 1-20 - I 0 3852 80 3804 DD 7655 25 8-3 - - - _ - - - / y , 390580 3.00 80°134 K -3 Basal - ; - _ - _ - - - 0 O/ / \ - 401°80 3970970.00 814987 K -2 g0 _, 412380 57500 0482.73 6-2 Basal e z s . / - - - - - - _ _ -- "" - 5312 BD 5264.00 12005.49 13417.82 Alban 97 • - - - - - -- - - - - ' O -F I [a y� p - - 5]88 BO 5]38 °0 _ _ _ _ ccOpp..� p p p - O O iL °59 Alban 96 .°0 655000 15°4 Top HRZ - LCU O o O. • O 0 O O O V ICD3- 124wpOk 6753 80 6705 00 1°33713 Base HRZ 7500- Top Nechelik Base Nuiqsut Top Nuiqsut O O O q O - 7500 1 6841°0 6793°0 16679 Top Kuparuk 6 1 1 1 1 1 1 1 1 1 1 1 1 1 t I I I I 1 1 I I I CD3 -101 FWwp02 id CD3 -101 FWwpXX T. - 6883 BO 6835 D0 1681574 Top KoperukC 6888 Bo 6640.00 16840 31 LCD -2500 0 2500 5000 7500 1900 12500 15000 6888 BD 884000 1°°4°31 Tap NUiasut 89880D 94000 1737899 B Vertical Section at 327.00 °(2500ft /in) ox 898°80 6800 1739199 as Nupsut 5 Nechelik Easting (4000 ft/in) I I I, 1 1 1 I, i i 1 1 1 1 1 1 1 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i i 1 I 1 1 1 1 1 1 1 1 1 I, 1 i, 1 1 1 1 1 1 1 1 i, ConocoPhillips(Alaska) Inc. -WNS - Date prepared Western North Slope 16:39, January 07 2010 CD3 Fiord Pad — ccD33-109 - CD3- 126wp02 - C►3- 106wp10 CD3 -125 p02 \ CD3- • 13•v30$1 CD3 -11 •' - = CD3- 1L1 CD3- 1Aw• •; •, • n,•. *rig - ss...) _ • - rise. „+ CD3 -' 11 - • = CD3 -1 2 - CD3 - •7 = CD3 -1 3 CD3 -31 Awp1 c _ \, D3 -30 ' A' :1 •06 = c– CD3- 4 1 - –z CD3-3 * _ a . W _ CD3- 124wp04 'D3-1315 a�. . ! i i - : D3 -307 _ A co _ ' D3- 7 ■ ��' •'� 0 �B - o - — ;� , i % fri 4 D3 -303 - . 4 . CD3- 199wp01 - • 0 CD3 _ 1 - II. 1 '`':' - CD3- 121wp02 CD3-3-04 CD3- 305PB1 = - CD3- 122wp05 CD3- 123wp02 CD3 -305 = , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Easting (4000 ft/in) • • Conoco Phillips HALL1BURTON Standard Proposal Report 00atp!:■pse:.:-„ EDM v16 Prod 11,iiicareo4ircilft*Reft_rence::;7.. Well Plan: CD3-124 . 11 . ConocoPhillips(Alaska) Inc. - --ii/DL-Reierenc.eIM2 - 7 -- E - '..154,- -- 4. - - - . ] ::. Plan: CD3-124 (36.3+12.5) @ 48.80ft (Doyon 19 Trpject Westem North Slope -.Mil • -Refarence:------ Plan' CD3-124 (36.3+12.5) @ 48.80ft (Doyon 19 -----------,------ - ;„;;;;; - _ -]:::•]-,---_--•••:-;;;; - S=Sifett4i - i - i - -, ] :..; CD3 Fjord Pad i_iNortfiRrAiranice:-...141::;;;;;;;;;; ,-0-''-'!"" True Well: -.--- - - - fAt: . " 4 Plan: CD3-124 - r-Siovey - CiidU4tii3n - Method: - ------ Minimum Curvature -Wafili01',11 Plan: CD2-124 .; ' •;-'-;::*;; ...]_]]...:::::':]]:-::--• ::•:;,-:::.';,;:-_-;-__]--11;61;:''::-:-.-----: .; Desiiiti. CD3-1241404 .. ProjeCt..1 :::-:1: , 11:,iii. , : - ., - 0 ,, ___ Western North Slope 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 factor Site '-'-'!, ':! :::::::...,,,,',:- , CD3 Fjord Pad Site Position: Northing: 469.98ft Latitude: 53° 58 43.652 N From: Map Easting: -401.25ft Longitude: 152° 19' 30.231 W ;Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88 ° I Welt :' ' Plan: CD3-124 Well Position +N/-S 0.00 ft Northing: 6,003,770.97ft • Latitude: 70° 25' 9.257 N +E/-W 0.00 ft Easting: 387,915.68ft • Longitude: 150° 54' 47.125 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft lAfefflitirt=: Plan CD2-124 .....,......... • ',„-----_, Magnetics1 i,r r-L :lii II ii0114 ' ' 1 : . ' , Of!! P le i;a i( FT iiilia i;: 0 P Aiiiii .10t4ii.0iiiiiiiiiii 6 iig H i:,V-rij7t--2-1,-Pk'liefi:EIP H :.:- - n :',11- 4iii li g --77 - . - -- - - ----- , ',0,1,-- -,=> . ■ I . ■ - ,4}........ ...„ .....- - 4 , --■ - - - ,- ... BGGM2007 1/7/2010 16.35 79.70 57,321 Design ___: 1 1:- ---_---_: -, ..,.:,:!::::::!,ft,- , -... CD3-124wp Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 yerticattei (f:) :0'.i2-j.-",._T-7::PR:.''.-''_!:-r;-"5jfV_t):e....j::f:f*-74:41.ifq':'-AVIIV-.:]]::iF-ti-4=-*1-=_--::::ll::(!1 V -_ - '.: - - _-__-!:.:!11: -, 36.30 0.00 0.00 327.00 Plan_Setilails ....''' -:-_ . - --- L:- - ft- : ]-7 7:10 .1EIV.: - .4-0: - -'-: : '; 71 !;04 - e -- 4f - ' 7 3W';'Z7- 1 -181k0E. - Za : :: : :T::. -- ' - _' - k ---:-=., ; 0 :1!H..... measurt S':' - .:"2 r -]_]': r 1:, 7 7- 136 00:::77 10:cntiaiiciii':ISOrtuth-]Perlkigiii 04.10... :1 - tft).: - -c- :_t_ it)L 36.30 0.00 0.00 36.30 -12.50 0.00 0.00 0.00 0.00 0.00 0.00 399.70 0.00 0.00 399.70 350.90 0.00 0.00 0.00 0.00 0.00 0.00 599.79 3.00 250.00 599.70 550.90 -1.79 -4.92 1.50 1.50 0.00 250.00 901.80 9.65 250.00 899.70 850.90 -13.16 -36.16 2.20 2.20 0.00 0.00 2,639.59 70.39 257.04 2,169.47 2,120.67 -271.20 -1,069.54 3.50 3.50 0.41 7.60 15,393.01 70.39 257.04 6,449.70 6,400.90 -2,965.26 -12,777.29 0.00 0.00 0.00 0.00 15,811.93 70.95 268.57 6,588.80 6,540.00 -3,014.59 -13,168.68 2.60 0.13 2.75 89.00 16,370.47 72.60 277.22 6,763.80 6,715.00 -2,987.63 -13,697.88 1.50 0.30 1.55 80.00 17,431.75 83.00 310.00 6,993.80 6,945.00 -2,573.50 -14,630.60 3.17 0.98 3.09 76.07 17,921.98 90.00 320.91 7,023.80 6,975.00 -2,225.38 -14,972.98 2.64 1.43 2.23 57.70 18,055.31 92.00 320.91 7,021.47 6,972.67 -2,121.91 -15,057.04 1.50 1.50 0.00 0.00 18,126.87 90.80 321.70 7,019.72 6,970.92 -2,066.09 -15,101.76 2.00 -1.67 1.10 146.69 19,996.64 90.80 321.70 6,993.49 6,944.69 -598.96 -16,260.59 0.00 0.00 0.00 0.00 20,607.29 -90.07 330.83 6,988.80 6,940.00 -91.71 -16,599.38 1.50 -0.12 1.50 94.52 24,470.69 90.07 330.84 6,983.80 6,935.00 3,281.78 -18,482.30 0.00 0.00 0.00 90.01 1/8/2010 10:23:33AM Page 2 COMPASS 2003.16 Build 69 L fk • • • Conoco Phillips HALL1BURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordin Reference: Well Plan: CD3-124 putupaay: _ ' ConocoPhillips(Alaska) Inc. .- __-]l-]- Plan: CD3-124 (36.3+12.5) @ 48.80ft (Doyon 19 . pi.ajed ,. .i: , !!i,...,,, i Western North Slope ''amoReference::-_-_ "L' - '!' Plan: CD3-124 (36.3+12.5) @ 48.80ft (Doyon 19 Site: - ---J , -_ ] : - ''_::' CD3 Fjord Pad -NortIviReferance:.- _ - True ! Illfalk - -:_!- Plan: CD3-124 -.SuiveicUlcidationAiOthod: : - -- Minimum Curvature ...,....„. „....„. iittatkoore Plan: CD2-124 Design: _]]];--_ . _. CD3-124wp04 , ,----_-- Planned Survey =-_ - Measured :,:: ' ] - 7 - iir - , --- '17 1 : - IT_71VeletiCal- 4 4 - _ , 7 7_ _7 '!!!!!::!:-: .:::::!:.::.: -7- ]:_l_747]_-]]]:7 - .:K: 74-inail - __7 - ];7]7::: . : - Map:- : ]]_ ; : :] . - : _-: - - - Et71 - : ] ] : : . "- Depth '!"''liflinatluti:. ---- Dbpth. _ ..': .:,7r.vbilii;-__ii:-]-_-] ' --. ::: 1 4H ---3 t.leitttlirg :J]_-4ii SaMint-g Mi.: Vert S (ft) --- _ _ ).H..41. ---)''::'?:' (f) ______-__ - __:,r. - - ---]:::- :...:.(ft) '-'_-_ _--- .. - (it) r,. : - -- -. -- --------_-----_ '. - ----- - r--:-_ ....H....:.:.' ------------- 36.30 0.00 0.00 36.30 -12.50 0.00 0.00 6,003,770.97 387,915.68 0.00 0.00 100.00 0.00 0.00 100.00 51.20 0.00 0.00 6,003,770.97 387,915.68 0.00 0.00 200.00 0.00 0.00 200.00 151.20 0.00 0.00 6,003,770.97 387,915.68 0.00 0.00 300.00 0.00 0.00 300.00 251.20 0.00 0.00 6,003,770.97 387,915.68 0.00 0.00 399.70 0.00 0.00 399.70 350.90 0.00 0.00 6,003,770.97 387,915.68 0.00 0.00 Start Build 1.50 ... . . 400.00 0.00 250.00 400.00 351.20 0.00 0.00 6,003,770.97 387,915.68 1.50 0.00 500.00 1.50 250.00 499.99 451.19 -0.45 -1.24 6,003,770.54 387,914.43 1.50 0.30 599.79 3.00 250.00 599.70 550.90 -1.79 -4.92 6,003,769.25 387,910.73 1.50 1.18 _ ... . - Start Build 2.20 600.00 3.00 250.00 599.91 551.11 -1.80 -4.93 6,003,769.25 387,910.72 0.00 1.18 700.00 5.21 250.00 699.65 650.85 -4.24 -11.66 6,003,766.90 387,903.96 2.20 2.79 800.00 7.41 250.00 799.03 750.23 -8.00 -21.98 6,003,763.30 387,893.58 2.20 5.26 900.00 9.61 250.00 897.93 849.13 -13.06 -35.88 6,003,758.45 387,879.61 2.20 8.59 901.80 9.65 250.00 899.70 850.90 -13.16 -36.16 6,003,758.36 387,879.32 2.20 8.66 Start DLS 3.50 TFO 7.60''!'''''''$.,., . . . _ 1,000.00 13.06 252.01 995.97 947.17 -19.40 -54.45 6,003,752.39 387,860.95 3.50 13.38 1,100.00 16.55 253.22 1,092.63 1,043.83 -27.01 -78.84 6,003,745.15 387,836.45 3.50 20.29 1,200.00 20.04 254.01 1,187.57 1,138.77 -35.84 -108.95 6,003,736.77 387,806.21 3.50 29.28 1,300.00 23.53 254.58 1,280.41 1,231.61 -45.88 -144.68 6,003,727.28 387,770.34 3.50 40.32 1,400.00 27.03 255.00 1,370.82 1,322.02 -57.07 -185.88 6,003,716.71 387,728.98 3.50 53.38 1,500.00 30.52 255.34 1,458.46 1,409.66 -69.38 -232.41 6,003,705.10 387,682.27 3.50 68.39 1,600.00 34.02 255.61 1,543.00 1,494.20 -82.76 -284.09 6,003,692.49 387,630.40 3.50 85.32 1,700.00 37.52 255.84 1,624.12 1,575.32 -97.16 -340.73 6,003,678.94 387,573.56 3.50 104.09 1,800.00 41.02 256.03 1,701.53 1,652.73 -112.54 -402.12 6,003,664.49 387,511.95 3.50 124.63 1,900.00 44.51 256.20 1,774.93 1,726.13 -128.82 -468.02 6,003,649.20 387,445.81 3.50 146.86 2,000.00 48.01 256.35 1,844.06 1,795.26 -145.96 -538.20 6,003,633.12 387,375.39 3.50 170.71 2,100.00 51.51 256.48 1,908.65 1,859.85 -163.88 -612.39 6,003,616.32 387,300.95 3.50 196.09 2,200.00 55.01 256.60 1,968.46 1,919.66 -182.52 -690.32 6,003,598.85 387,222.76 3.50 222.90 2,300.00 58.51 256.72 2,023.26 1,974.46 -201.82 -771.68 6,003,580.78 387,141.12 3.50 251.03 2,400.00 62.01 256.82 2,072.87 2,024.07 -221.69 -856.19 6,003,562.18 387,056.33 3.50 280.39 2,500.00 65.51 256.92 2,117.08 2,068.28 -242.06 -943.53 6,003,543.12 386,968.71 3.50 310.87 2,600.00 69.00 257.01 2,155.73 2,106.93 -262.87 -1,033.36 6,003,523.67 386,878.58 3.50 342.35 2,639.59 70.39 257.04 2,169.47 2,120.67 -271.20 -1,069.54 6,003,515.88 386,842.28 3.50 355.06 Start 12753.42 hold__42639.50 MD 2,700.00 70.39 257.04 2,189.75 2,140.95 -283.96 -1,125.00 6,003,503.96 386,786.64 0.00 374.56 2,800.00 70.39 257.04 2,223.31 2,174.51 -305.09 -1,216.80 6,003,484.21 386,694.54 0.00 406.85 2,900.00 70.39 257.04 2,256.87 2,208.07 -326.21 -1,308.60 6,003,464.47 386,602.44 0.00 439.13 3,000.00 70.39 257.04 2,290.43 2,241.63 -347.34 -1,400.40 6,003,444.73 386,510.34 0.00 471.41 3,100.00 70.39 257.04 2,323.99 2,275.19 -368.46 -1,492.20 6,003,424.99 386,418.24 0.00 503.69 3,200.00 70.39 257.04 2,357.55 2,308.75 -389.58 -1,584.00 6,003,405.25 386,326.14 0.00 535.98 3,300.00 70.39 257.04 2,391.11 2,342.31 -410.71 -1,675.80 6,003,385.50 386,234.04 0.00 568.26 3,400.00 70.39 257.04 2,424.68 2,375.88 -431.83 -1,767.60 6,003,365.76 386,141.94 0.00 600.54 3,500.00 70.39 257.04 2,458.24 2,409.44 -452.96 -1,859.40 6,003,346.02 386,049.84 0.00 632.82 1/8/2010 10:23:33AM Page 3 COMPASS 2003.16 Build 69 - • i -°‘ ! .P ! 11/4 1 , I , I 1 1 . . ,,.... , • • ConocoPhillips HALL1BURTON Standard Proposal Report s Database EDM , w16 Prod _ __., _ -� � .,.h= ., �� .� �a. ,, ,: ,...�._.�..� ��,. It Coin n ConocoPhillips(Alaska) Plan: CD3 -124 (36.3+12.5) @ 48.80ft Do o �Illulllll ;. Local Co- ordinate Reference Well Plan: CD3 -124 pa Y = coPhillips(A Inc. TVD Re fe� s enc e - ( ) ( y n 19 Ij Project Western North Slope MD Reference CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 Plan: ' Sites CD3 Fjord Pad North Reference: ` q True Yllell_ Plan: CD3 124 Survey Calculation Method Minimum Curvature h :I e W Ilhare: Plan: CD2 -124 D -124w 4 Desig n C 3 p0 - __/____--- --- N,,,,, _,,,.. -- EL,.... i Planned Survey Measured.- VerticaF Map Map � � h� 1!!lov g Depth ..,' Inclination Azimuth Deptit TVDss +NI-S +Ef-W Northin Easing DES ,iil''�P'i''+ ertSection iilllu �i o - -- , 6, - _ 4f } - . t) ft .,! { � ` (ft) -- 'ci (ftj �� 3,555.31 70.39 257.04 2,476.80 2,428.00 2,�i2tr�la M . _ -464.64 -1,910.18 6,003,335.10 385,998.90 0.00 650.68 C -30 '„ 3,600.00 70.39 257.04 2,491.80 2,443.00 - 474.08 - 1,951.20 6,003,326.28 385,957.74 0.00 665.10 3,624.44 70.39 257.04 2,500.00 2,451.20 - 479.24 - 1,973.64 6,003,321.46 385,935.24 0.00 672.99 10 - 3/4" x 13 - - 3,700.00 70.39 257.04 2,525.36 2,476.56 - 495.21 - 2,043.00 6,003,306.54 385,865.64 0.00 697.39 3,800.00 70.39 257.04 2,558.92 2,510.12 - 516.33 - 2,134.81 6,003,286.80 385,773.55 0.00 729.67 3,900.00 70.39 257.04 2,592.48 2,543.68 - 537.45 - 2,226.61 6,003,267.05 385,681.45 0.00 761.95 4,000.00 70.39 257.04 2,626.04 2,577.24 - 558.58 - 2,318.41 6,003,247.31 385,589.35 0.00 794.23 4,100.00 70.39 257.04 2,659.61 2,610.81 - 579.70 - 2,410.21 6,003,227.57 385,497.25 0.00 826.51 4,200.00 70.39 257.04 2,693.17 2,644.37 - 600.83 - 2,502.01 6,003,207.83 385,405.15 0.00 858.80 4,300.00 70.39 257.04 2,726.73 2,677.93 - 621.95 - 2,593.81 6,003,188.09 385,313.05 0.00 891.08 4,400.00 70.39 257.04 2,760.29 2,711.49 - 643.07 - 2,685.61 6,003,168.35 385,220.95 0.00 923.36 4,500.00 70.39 257.04 2,793.85 2,745.05 - 664.20 - 2,777.41 6,003,148.60 385,128.85 0.00 955.64 4,600.00 70.39 257.04 2,827.41 2,778.61 - 685.32 - 2,869.21 6,003,128.86 385,036.75 0.00 987.92 4,678.62 70.39 257.04 2,853.80 2,805.00 - 701.93 - 2,941.39 6,003,113.34 384,964.33 0.00 1,013.31 C-20 - ' - *Lis .39 257.04 2,860.97 2,812.17 - 706.45 - 2,961.01 6,003,109.12 384,944.65 0.00 1,020.21 4,800.00 70.39 257.04 2,894.54 2,845.74 - 727.57 - 3,052.81 6,003,089.38 384,852.55 0.00 1,052.49 4,900.00 70.39 257.04 2,928.10 2,879.30 - 748.70 - 3,144.61 6,003,069.64 384,760.45 0.00 1,084.77 5,000.00 70.39 257.04 2,961.66 2,912.86 - 769.82 - 3,236.42 6,003,049.90 384,668.35 0.00 1,117.05 5,100.00 70.39 257.04 2,995.22 2,946.42 - 790.94 - 3,328.22 6,003,030.15 384,576.25 0.00 1,149.34 5,200.00 70.39 257.04 3,028.78 2,979.98 - 812.07 - 3,420.02 6,003,010.41 384,484.15 0.00 1,181.62 5,300.00 70.39 257.04 3,062.34 3,013.54 - 833.19 - 3,511.82 6,002,990.67 384,392.05 0.00 1,213.90 5,400.00 70.39 257.04 3,095.90 3,047.10 - 854.32 - 3,603.62 6,002,970.93 384,299.95 0.00 1,246.18 5,500.00 70.39 257.04 3,129.47 3,080.67 - 875.44 - 3,695.42 6,002,951.19 384,207.85 0.00 1,278.46 5,600.00 70.39 257.04 3,163.03 3,114.23 - 896.56 - 3,787.22 6,002,931.44 384,115.75 0.00 1,310.75 5,700.00 70.39 257.04 3,196.59 3,147.79 - 917.69 - 3,879.02 6,002,911.70 384,023.65 0.00 1,343.03 5,800.00 70.39 257.04 3,230.15 3,181.35 - 938.81 - 3,970.82 6,002,891.96 383,931.55 0.00 1,375.31 5,900.00 70.39 257.04 3,263.71 3,214.91 - 959.94 - 4,062.62 6,002,872.22 383,839.45 0.00 1,407.59 6,000.00 70.39 257.04 3,297.27 3,248.47 - 981.06 - 4,154.42 6,002,852.48 383,747.35 0.00 1,439.87 6,100.00 70.39 257.04 3,330.83 3,282.03 - 1,002.19 - 4,246.23 6,002,832.74 383,655.25 0.00 1,472.16 6,200.00 70.39 257.04 3,364.40 3,315.60 - 1,023.31 - 4,338.03 6,002,812.99 383,563.15 0.00 1,504.44 6,300.00 70.39 257.04 3,397.96 3,349.16 - 1,044.43 - 4,429.83 6,002,793.25 383,471.05 0.00 1,536.72 6,400.00 70.39 257.04 3,431.52 3,382.72 - 1,065.56 - 4,521.63 6,002,773.51 383,378.95 0.00 1,569.00 6,500.00 70.39 257.04 3,465.08 3,416.28 - 1,086.68 - 4,613.43 6,002,753.77 383,286.85 0.00 1,601.28 6,600.00 70.39 257.04 3,498.64 3,449.84 - 1,107.81 - 4,705.23 6,002,734.03 383,194.75 0.00 1,633.57 6,700.00 70.39 257.04 3,532.20 3,483.40 - 1,128.93 - 4,797.03 6,002,714.29 383,102.65 0.00 1,665.85 6,800.00 70.39 257.04 3,565.76 3,516.96 - 1,150.05 - 4,888.83 6,002,694.54 383,010.55 0.00 1,698.13 6,900.00 70.39 257.04 3,599.33 3,550.53 - 1,171.18 - 4,980.63 6,002,674.80 382,918.45 0.00 1,730.41 7,000.00 70.39 257.04 3,632.89 3,584.09 - 1,192.30 - 5,072.43 6,002,655.06 382,826.35 0.00 1,762.70 7,100.00 70.39 257.04 3,666.45 3,617.65 - 1,213.43 - 5,164.23 6,002,635.32 382,734.25 0.00 1,794.98 7,200.00 70.39 257.04 3,700.01 3,651.21 - 1,234.55 - 5,256.03 6,002,615.58 382,642.15 0.00 1,827.26 7,300.00 70.39 257.04 3,733.57 3,684.77 - 1,255.68 - 5,347.84 6,002,595.84 382,550.05 0.00 1,859.54 7,400.00 70.39 257.04 3,767.13 3,718.33 - 1,276.80 - 5,439.64 6,002,576.09 382,457.95 0.00 1,891.82 1/8/2010 10:23:33AM Page 4 COMPASS 2003.16 Build 69 a f ^p 1 t� 1 L' . • ConocoPhillips Standard Proposal Report Database: ' i EDM v16 Prod Local Co- ordinate R e f erence W ell Pla n. CD3 C - (Doyon 19 124 Com an ' 411 ConocoPhillips(Alaska) Inc. TVD Reference: it Plan: CD3 -124 (36.3+12.5) 48 80ft I Project: Western North Slope MD.Reference: I ' I Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 Site; I II CD3 Fjord Pad North Reference - r True Well: „idI Plan: CD3 -124 , Survey Calculation Method Minimum Curvature Iii We'Ilbore Plan: CD2 -124 Design: it CD3- 124Wp04 I " mu,rr r w mumco mr .I .. Planned Survey Measured Verticai Map Map i' I I u �i y; lil ilii;�i p *NI-S +Et -W Northing - Easting DLS Vet Section De th Inclination Azimuth iiep NDss (ft) t °) = - t = f ( I :-:7:--_-_ ) Eft) I t) �I 3 , : :111111: 7,500.00 70.39 257.04 3,800.69 3,751.89 - 1,297.92 - 5,531.44 6,002,556.35 382,365.85 0.00 ,924.11 7,600.00 70.39 257.04 3,834.26 3,785.46 - 1,319.05 - 5,623.24 6,002,536.61 382,273.75 0.00 1,956.39 7,655.25 70.39 257.04 3,852.80 3,804.00 - 1,330.72 - 5,673.96 6,002,525.70 382,222.86 0.00 1,974.23 K - 3 7,700.00 70.39 257.04 3,867.82 3,819.02 - 1,340.17 - 5,715.04 6,002,516.87 382,181.65 0.00 1,988.67 7,800.00 70.39 257.04 3,901.38 3,852.58 - 1,361.30 - 5,806.84 6,002,497.13 382,089.55 0.00 2,020.95 7,900.00 70.39 257.04 3,934.94 3,886.14 - 1,382.42 - 5,898.64 6,002,477.38 381,997.45 0.00 2,053.23 8,000.00 70.39 257.04 3,968.50 3,919.70 - 1,403.54 - 5,990.44 6,002,457.64 381,905.35 0.00 2,085.52 8,081.34 70.39 257.04 3,995.80 3,947.00 - 1,420.73 - 6,065.11 6,002,441.59 381,830.44 0.00 2,111.77 K Basal 8,100.00 70.39 257.04 4,002.06 3,953.26 - 1,424.67 - 6,082.24 6,002,437.90 381,813.25 0.00 2,117.80 8,149.87 70.39 257.04 4,018.80 3,970.00 - 1,435.20 - 6,128.02 6,002,428.06 381,767.32 0.00 2,133.90 K - 2 8,200.00 70.39 257.04 4,035.62 3,986.82 - 1,445.79 - 6,174.04 6,002,418.16 381,721.15 0.00 2,150.08 8,300.00 70.39 257.04 4,069.19 4,020.39 - 1,466.92 - 6,265.84 6,002,398.42 381,629.05 0.00 2,182.36 8,400.00 70.39 257.04 4,102.75 4,053.95 - 1,488.04 - 6,357.65 6,002,378.68 381,536.95 0.00 2,214.65 8,462.73 70.39 257.04 4,123.80 4,075.00 - 1,501.29 - 6,415.23 6,002,366.29 381,479.18 0.00 2,234.90 K Basal e: 8,500.00 70.39 257.04 4,136.31 4,087.51 - 1,509.17 - 6,449.45 6,002,358.93 381,444.85 0.00 2,246.93 8,600.00 70.39 257.04 4,169.87 4,121.07 - 1,530.29 - 6,541.25 6,002,339.19 381,352.75 0.00 2,279.21 8,700.00 70.39 257.04 4,203.43 4,154.63 - 1,551.41 - 6,633.05 6,002,319.45 381,260.66 0.00 2,311.49 8,800.00 70.39 257.04 4,236.99 4,188.19 - 1,572.54 - 6,724.85 6,002,299.71 381,168.56 0.00 2,343.77 8,900.00 70.39 257.04 4,270.55 4,221.75 - 1,593.66 - 6,816.65 6,002,279.97 381,076.46 0.00 2,376.06 9,000.00 70.39 257.04 4,304.12 4,255.32 - 1,614.79 - 6,908.45 6,002,260.23 380,984.36 0.00 2,408.34 9,100.00 70.39 257.04 4,337.68 4,288.88 - 1,635.91 - 7,000.25 6,002,240.48 380,892.26 0.00 2,440.62 9,200.00 70.39 257.04 4,371.24 4,322.44 - 1,657.04 - 7,092.05 6,002,220.74 380,800.16 0.00 2,472.90 9,300.00 70.39 257.04 4,404.80 4,356.00 - 1,678.16 - 7,183.85 6,002,201.00 380,708.06 0.00 2,505.18 9,400.00 70.39 257.04 4,438.36 4,389.56 - 1,699.28 - 7,275.65 6,002,181.26 380,615.96 0.00 2,537.47 9,500.00 70.39 257.04 4,471.92 4,423.12 - 1,720.41 - 7,367.45 6,002,161.52 380,523.86 0.00 2,569.75 9,600.00 70.39 257.04 4,505.48 4,456.68 - 1,741.53 - 7,459.26 6,002,141.77 380,431.76 0.00 2,602.03 9,700.00 70.39 257.04 4,539.05 4,490.25 - 1,762.66 - 7,551.06 6,002,122.03 380,339.66 0.00 2,634.31 9,800.00 70.39 257.04 4,572.61 4,523.81 - 1,783.78 - 7,642.86 6,002,102.29 380,247.56 0.00 2,666.59 9,900.00 70.39 257.04 4,606.17 4,557.37 - 1,804.90 - 7,734.66 6,002,082.55 380,155.46 0.00 2,698.88 10,000.00 70.39 257.04 4,639.73 4,590.93 - 1,826.03 - 7,826.46 6,002,062.81 380,063.36 0.00 2,731.16 10,100.00 70.39 257.04 4,673.29 4,624.49 - 1,847.15 - 7,918.26 6,002,043.07 379,971.26 0.00 2,763.44 10,200.00 70.39 257.04 4,706.85 4,658.05 - 1,868.28 - 8,010.06 6,002,023.32 379,879.16 0.00 2,795.72 10,300.00 70.39 257.04 4,740.41 4,691.61 - 1,889.40 - 8,101.86 6,002,003.58 379,787.06 0.00 2,828.01 10,400.00 70.39 257.04 4,773.98 4,725.18 - 1,910.53 - 8,193.66 6,001,983.84 379,694.96 0.00 2,860.29 10,500.00 70.39 257.04 4,807.54 4,758.74 - 1,931.65 - 8,285.46 6,001,964.10 379,602.86 0.00 2,892.57 10,600.00 70.39 257.04 4,841.10 4,792.30 - 1,952.77 - 8,377.26 6,001,944.36 379,510.76 0.00 2,924.85 10,700.00 70.39 257.04 4,874.66 4,825.86 - 1,973.90 - 8,469.07 6,001,924.62 379,418.66 0.00 2,957.13 10,800.00 70.39 257.04 4,908.22 4,859.42 - 1,995.02 - 8,560.87 6,001,904.87 379,326.56 0.00 2,989.42 10,900.00 70.39 257.04 4,941.78 4,892.98 - 2,016.15 - 8,652.67 6,001,885.13 379,234.46 0.00 3,021.70 11,000.00 70.39 257.04 4,975.34 4,926.54 - 2,037.27 - 8,744.47 6,001,865.39 379,142.36 0.00 3,053.98 11,100.00 70.39 257.04 5,008.91 4,960.11 - 2,058.39 - 8,836.27 6,001,845.65 379,050.26 0.00 3,086.26 1/8/2010 10:23:33AM Page 5 COMPASS 2003.16 Build 69 • R!G?NAL • 0 Conoco Phillips HALLIBURTON Standard Proposal- Report : -----, ---- Database: - ------ EDM v16 Prod ,7Local Co-ordinate Reference Well Plan: CD3-124 Company: -: ConocoPhillips(Alaska) Inc. :TVD Refetence:: :: -„]„„ „: -,::::::„-_-_-„i:_ij„ Plan: CD3-124 (36.3+12.5) @ 48.80ft (Doyon 19 Project --- -„-]!] _: Westem North Slope MD Reference: H„::- ------- : - ' ' - Plan CD3-124 (36.3+12.5) @ 48.80ft (Doyon 19 Site: : ' - CD3 Fjord Pad North Reference: , . :=a; ::::::::H:,:: True --- --_ „ „„:„---, : ,::1 - ,iWek*,*, a :, N Plan: CD3-124 :::Suivey CalctilatiotEMettiod: Minimum Curvature li Weillboret''' ". Plan: CD2-124 - - - - Design: :::,:1:::::: CD3-124wp04 _Planned"Slipfey Measured : :] - __av- : :ii _] 1:::::::11,: - . : : : v er ti ca l, ::: :: - ---:- --------, , ::::::: ---,-----,-, ,:!,::::: - -_-- - i,- - -=Map :'' ":'":;::,- Map ] : Depth: :VInclination - -Azimuth : :::, Depth Nbiel! +E!-W : :: r-: Northing : -!]]]]]]-]]]]: as'iing :414:,:::: ]]: ]DLS ]Afeit:Seedon ::11111111 (fti H :: ft ri-,i -I(*) (f.t) r ft : ' () ]::: H "(ft) -]-;]] ,:: :: (ft) :!:11:i"!::: ---4- - (ft) ]---- &97. - :l ]-,--- : ---i-]-i- ::: -- 11,200.00 70.39 257.04 5,042.47 4,993.67 -2,079.52 -8,928.07 6,001,825.91 378,958.16 0.00 3,118.54 11,300.00 70.39 257.04 5,076.03 5,027.23 -2,100.64 -9,019.87 6,001,806.17 378,866.06 0.00 3,150.83 11,400.00 70.39 257.04 5,109.59 5,060.79 -2,121.77 -9,111.67 6,001,786.42 378,773.96 0.00 3,183.11 11,500.00 70.39 257.04 5,143.15 5,094.35 -2,142.89 -9,203.47 6,001,766.68 378,681.86 0.00 3,215.39 11,600.00 70.39 257.04 5,176.71 5,127.91 -2,164.02 -9,295.27 6,001,746.94 378,589.76 0.00 3,247.67 11,700.00 70.39 257.04 5,210.27 5,161.47 -2,185.14 -9,387.07 6,001,727.20 378,497.66 0.00 3,279.95 11,800.00 70.39 257.04 5,243.84 5,195.04 -2,206.26 -9,478.87 6,001,707.46 378,405.56 0.00 3,312.24 11,900.00 70.39 257.04 5,277.40 5,228.60 -2,227.39 -9,570.68 6,001,687.71 378,313.46 0.00 3,344.52 12,000.00 70.39 257.04 5,310.96 5,262.16 -2,248.51 -9,662.48 6,001,667.97 378,221.36 0.00 3,376.80 12,005.49 70.39 257.04 5,312.80 5,264.00 -2,249.67 -9,667.51 6,001,666.89 378,216.31 0.00 3,378.57 Albian 97 12,100.00 70.39 257.04 5,344.52 5,295.72 -2,269.64 -9,754.28 6,001,648.23 378,129.26 0.00 3,409.08 12,200.00 70.39 257.04 5,378.08 5,329.28 -2,290.76 -9,846.08 6,001,628.49 378,037.16 0.00 3,441.37 12,300.00 70.39 257.04 5,411.64 5,362.84 -2,311.88 -9,937.88 6,001,608.75 377,945.06 0.00 3,473.65 12,400.00 70.39 257.04 5,445.20 5,396.40 -2,333.01 -10,029.68 6,001,589.01 377,852.96 0.00 3,505.93 12,500.00 70.39 257.04 5,478.77 5,429.97 -2,354.13 -10,121.48 6,001,569.26 377,760.86 0.00 3,538.21 12,600.00 70.39 257.04 5,512.33 5,463.53 -2,375.26 -10,213.28 6,001,549.52 377,668.76 0.00 3,570.49 12,700.00 70.39 257.04 5,545.89 5,497.09 -2,396.38 -10,305.08 6,001,529.78 377,576.66 0.00 3,602.78 12,800.00 70.39 257.04 5,579.45 5,530.65 -2,417.51 -10,396.88 6,001,510.04 377,484.56 0.00 3,635.06 12,900.00 70.39 257.04 5,613.01 5,564.21 -2,438.63 -10,488.68 6,001,490.30 377,392.46 0.00 3,667.34 13,000.00 70.39 257.04 5,646.57 5,597.77 -2,459.75 -10,580.49 6,001,470.56 377,300.36 0.00 3,699.62 13,100.00 70.39 257.04 5,680.13 5,631.33 -2,480.88 -10,672.29 6,001,450.81 377,208.26 0.00 3,731.90 13,200.00 70.39 257.04 5,713.70 5,664.90 -2,502.00 -10,764.09 6,001,431.07 377,116.16 0.00 3,764.19 13,300.00 70.39 257.04 5,747.26 5,698.46 -2,523.13 -10,855.89 6,001,411.33 377,024.06 0.00 3,796.47 13,400.00 70.39 257.04 5,780.82 5,732.02 -2,544.25 -10,947.69 6,001,391.59 376,931.96 0.00 3,828.75 13,417.82 70.39 257.04 5,786.80 5,738.00 -2,548.02 -10,964.05 6,001,388.07 376,915.55 0.00 3,834.50 Albian: 96 13,500.00 70.39 257.04 5,814.38 5,765.58 -2,565.37 -11,039.49 6,001,371.85 376,839.86 0.00 3,861.03 13,600.00 70.39 257.04 5,847.94 5,799.14 -2,586.50 -11,131.29 6,001,352.11 376,747.77 0.00 3,893.31 13,700.00 70.39 257.04 5,881.50 5,832.70 -2,607.62 -11,223.09 6,001,332.36 376,655.67 0.00 3,925.60 13,800.00 70.39 257.04 5,915.06 5,866.26 -2,628.75 -11,314.89 6,001,312.62 376,563.57 0.00 3,957.88 13,900.00 70.39 257.04 5,948.63 5,899.83 -2,649.87 -11,406.69 6,001,292.88 376,471.47 0.00 3,990.16 14,000.00 70.39 257.04 5,982.19 5,933.39 -2,671.00 -11,498.49 6,001,273.14 376,379.37 0.00 4,022.44 14,100.00 70.39 257.04 6,015.75 5,966.95 -2,692.12 -11,590.29 6,001,253.40 376,287.27 0.00 4,054.73 14,200.00 70.39 257.04 6,049.31 6,000.51 -2,713.24 -11,682.10 6,001,233.65 376,195.17 0.00 4,087.01 14,300.00 70.39 257.04 6,082.87 6,034.07 -2,734.37 -11,773.90 6,001,213.91 376,103.07 0.00 4,119.29 14,400.00 70.39 257.04 6,116.43 6,067.63 -2,755.49 -11,865.70 6,001,194.17 376,010.97 0.00 4,151.57 14,500.00 70.39 257.04 6,149.99 6,101.19 -2,776.62 -11,957.50 6,001,174.43 375,918.87 0.00 4,183.85 14,600.00 70.39 257.04 6,183.56 6,134.76 -2,797.74 -12,049.30 6,001,154.69 375,826.77 0.00 4,216.14 14,700.00 70.39 257.04 6,217.12 6,168.32 -2,818.86 -12,141.10 6,001,134.95 375,734.67 0.00 4,248.42 14,800.00 70.39 257.04 6,250.68 6,201.88 -2,839.99 -12,232.90 6,001,115.20 375,642.57 0.00 4,280.70 14,900.00 70.39 257.04 6,284.24 6,235.44 -2,861.11 -12,324.70 6,001,095.46 375,550.47 0.00 4,312.98 15,000.00 70.39 257.04 6,317.80 6,269.00 -2,882.24 -12,416.50 6,001,075.72 375,458.37 0.00 4,345.26 15,100.00 70.39 257.04 6,351.36 6,302.56 -2,903.36 -12,508.30 6,001,055.98 375,366.27 0.00 4,377.55 15,200.00 70.39 257.04 6,384.92 6,336.12 -2,924.49 -12,600.10 6,001,036.24 375,274.17 0.00 4,409.83 1/8/2010 10:23.33AM Page 6 COMPASS 2003.16 Build 69 C 1 . • : ..• , • . ConocoPhillips Standard Proposal Report C om p an e ' ConocoPhillips(Alaska) ps(Alaska) Inc. TVD Reference Reference Well I:I P CD3 12 (36.3 +12.5) @ 48.80ft Do on 19 Local Co- ordinate , p Y (Doyon iij .Project = Western North Slope MD Reference Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 ull Situ CD3 Fjord Pad l North Reference True WeIL Plan: CD3 -124 Survey Calculation Method - M inimu m Curvature We41)ore_ , Plan: CD2 -124 Design CD3124wp04 -''- - - - -. -, Planned Survey - Me a su red + Vertical = M ap Map n Depth tnctiriation , Azimuth Depth ''' TVDss +NN11 -S +EJ W Northing = Eastinq � - DLS Vert Section (o) (ft} ft (ft) -_- (ftj ' (ft) (ft) u 6,369 69 i : " 15,300.00 70.39 257.04 6,418.49 6,369.69 - 2,945.61 - 12,691.91 6,001,016.50 375,182.07 0.00 4,442.11 15,393.01 70.39 257.04 6,449.70 6,400.90 - 2,965.26 - 12,777.29 6,000,998.13 375,096.41 0.00 4,472.14 Start DLS 2.60 TFO 89.00 15,400.00 70.39 257.23 6,452.05 6,403.25 - 2,966.72 - 12,783.71 6,000,996.76 375,089.97 2.60 4,474.40 15,500.00 70.46 259.99 6,485.55 6,436.75 - 2,985.32 - 12,876.07 6,000,979.56 374,997.35 2.60 4,509.11 15,600.00 70.57 262.75 6,518.91 6,470.11 - 2,999.47 - 12,969.26 6,000,966.81 374,903.96 2.60 4,548.00 15,700.00 70.73 265.50 6,552.05 6,503.25 - 3,009.12 - 13,063.11 6,000,958.57 374,809.99 2.60 4,591.01 15,800.00 70.92 268.24 6,584.90 6,536.10 - 3,014.28 - 13,157.41 6,000,954.83 374,715.63 2.60 4,638.05 15,811.93 70.95 268.57 6,588.80 6,540.00 - 3,014.59 - 13,168.68 6,000,954.69 374,704.35 2.60 4,643.93 Start DLS 1.50 TFO 80.00 15,842.63 71.03 269.05 6,598.80 6,550.00 - 3,015.19 - 13,197.69 6,000,954.52 374,675.34 1.50 4,659.23 Top HRZ - „ - 15,900.00 71.18 269.95 6,617.38 6,568.58 - 3,015.67 - 13,251.97 6,000,954.86 374,621.06 1.50 4,688.39 16,000.00 71.46 271.50 6,649.41 6,600.61 - 3,014.47 - 13,346.69 6,000,957.48 374,526.38 1.50 4,740.98 16,100.00 71.75 273.05 6,680.97 6,632.17 - 3,010.70 - 13,441.50 6,000,962.68 374,431.64 1.50 4,795.78 16,200.00 72.05 274.60 6,712.04 6,663.24 - 3,004.35 - 13,536.34 6,000,970.44 374,336.92 1.50 4,852.76 16,300.00 72.37 276.14 6,742.59 6,693.79 - 2,995.45 - 13,631.14 6,000,980.77 374,242.27 1.50 4,911.86 16,337.13 72.49 276.71 6,753.80 6,705.00 - 2,991.49 - 13,666.31 6,000,985.26 374,207.16 1.50 4,934.34 Base HRZ - 16,370.47 72.60 277.22 6,763.80 6,715.00 - 2,987.63 - 13,697.88 6,000,989.59 374,175.66 1.50 4,954.76 Start DLS 3.17 TFO 76.07 16,400.00 72.83 278.17 6,772.58 6,723.78 - 2,983.85 - 13,725.82 6,000,993.78 374,147.78 3.17 4,973.15 16,500.00 73.63 281.37 6,801.44 6,752.64 - 2,967.60 - 13,820.17 6,001,011.45 374,053.70 3.17 5,038.16 16,508.39 73.70 281.64 6,803.80 6,755.00 - 2,966.00 - 13,828.05 6,001,013.17 374,045.84 3.17 5,043.80 K -1, 16,600.00 74.48 284.54 6,828.92 6,780.12 - 2,946.04 - 13,913.85 6,001,034.41 373,960.36 3.17 5,107.27 i 16,648.79 - 74.91 286.08 6,841.80 6,793.00 - 2,933.61 - 13,959.24 6,001,047.52 373,915.16 3.17 5,142.42 Top Kuparuk D 1 6,700.00 75.37 287.69 6,854.93 6,806.13 - 2,919.23 - 14,006.60 6,001,062.61 373,868.03 3.17 5,180.27 16,800.00 76.31 290.81 6,879.39 6,830.59 - 2,887.26 - 14,098.13 6,001,095.94 373,777.00 3.17 5,256.93 16,818.74 76.49 291.39 6,883.80 6,835.00 - 2,880.70 - 14,115.12 6,001,102.76 373,760.11 3.17 5,271.69 Top Kuparuk C .. 16,840.31 76.70 292.06 6,888.80 6,840.00 - 2,872.93 - 14,134.61 6,001,110.82 373,740.74 3.17 5,288.82 LCU - Top Nuigsut _ -- 16,900.00 77.29 293.91 6,902.23 6,853.43 - 2,850.23 - 14,188.15 6,001,134.32 373,687.55 3.17 5,337.02 17,000.00 78.30 296.98 6,923.38 6,874.58 - 2,808.24 - 14,276.39 6,001,177.63 373,599.96 3.17 5,420.30 17,078.75 79.12 299.38 6,938.80 6,890.00 - 2,771.77 - 14,344.46 6,001,215.11 373,532.45 3.17 5,487.95 Base Nuigsut 17,100.00 79.34 300.03 6,942.77 6,893.97 - 2,761.42 - 14,362.59 6,001,225.73 373,514.48 3.17 5,506.50 17,200.00 80.42 303.05 6,960.34 6,911.54 - 2,709.93 - 14,446.48 6,001,278.47 373,431.38 3.17 5,595.38 17,300.00 81.52 306.06 6,976.05 6,927.25 - 2,653.91 - 14,527.80 6,001,335.70 , 373,350.92 3.17 5,686.65 17,391.99 82.55 308.81 6,988.80 6,940.00 - 2,598.53 - 14,600.13 6,001,392.15 373,279.44 3.17 5,772.49 Top Neheiik - - 17,400.00 82.64 309.05 6,989.83 6,941.03 - 2,593.54 - 14,606.30 6,001,397.24 373,273.34 3.17 5,780.04 1/8/2010 10:23:33AM Page 7 COMPASS 2003.16 Build 69 • • ConocoPhillips HALL1BURTON Standard Proposal Report . _ __ .. __ - Database: '' EDM v16 Prod LocatCo- ordinat Reference: Well Plan: CD3 -124 Company : ConocoPhillips(Alaska) Inc. TVDReference: - Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 u Project: . Western North Slope MD Reference: -- Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 Stte: '' " CD3 Fjord Pad North Reference True Well Plan: CD3 -124 `SurveyCalcutatiot[ Method ' Minimum Curvature W ilbore: Plan: CD2-124 D CD3 124wp04 1:;:',;::'; lanned Survey u' : _ .. mu, Measured;:,,,, Vertical Map ': Map Depth t Inclination Azimuth Depth TVDss +NtS +Et Vlf Northing Easting - LS D ° i Vert Se tlan _ - . 1 (ft} [°} ( °} (ft ft -_(ft} (ft) (ft) '''Ii (ft) 6945- €id + - 17,431.75 83.00 310.00 6,993.80 6,945.00 - 2,573.49 - 14,630.60 6,001,417.64 373,249.35 3.17 5,810.08 - Start DLS'2.64 TFO 57.70 - 7-518" X 9 -718" 17,500.00 83.97 311.53 7,001.55 6,952.75 - 2,529.22 - 14,681.95 6,001,462.68 373,198.67 2.64 5,875.19 17,600.00 85.39 313.76 7,010.83 6,962.03 - 2,461.77 - 14,755.18 6,001,531.22 373,126.46 2.64 5,971.64 17,700.00 86.82 315.99 7,017.63 6,968.83 - 2,391.37 - 14,825.87 6,001,602.66 373,056.85 2.64 6,069.17 17,800.00 88.25 318.21 7,021.94 6,973.14 - 2,318.20 - 14,893.88 6,001,676.84 372,989.95 2.64 6,167.58 17,900.00 89.68 320.42 7,023.74 6,974.94 - 2,242.38 - 14,959.05 6,001,753.62 372,925.93 2.64 6,266.66 17,921.98 90.00 320.91 7,023.80 6,975.00 - 2,225.38 - 14,972.98 6,001,770.83 372,912.26 2.64 6,288.51 Start Build 1.50 - 18,000.00 91.17 320.91 7,023.00 6,974.20 - 2,164.83 - 15,022.17 6,001,832.10 372,863.99 1.50 6,366.08 18,055.31 92.00 320.91 7,021.47 6,972.67 - 2,121.91 - 15,057.04 6,001,875.54 372,829.77 1.50 6,421.06 Start DLS 2.00 TFO, 447.75 18,100.00 91.25 321.40 7,020.20 6,971.40 - 2,087.13 - 15,085.05 6,001,910.74 372,802.29 2.00 6,465.50 18,125.96 90.82 321.69 7,019.74 6,970.94 - 2,066.80 - 15,101.20 6,001,931.31 372,786.45 2.00 6,491.34 Start 1867.0 hold at 18125.96 MD 18,126.87 90.80 321.70 7,019.72 6,970.92 - 2,066.09 - 15,101.76 6,001,932.02 372,785.90 2.00 6,492.24 18,200.00 90.80 321.70 7,018.70 6,969.90 - 2,008.70 - 15,147.08 6,001,990.08 372,741.44 0.00 6,565.05 18,300.00 90.80 321.70 7,017.29 6,968.49 - 1,930.24 - 15,209.06 6,002,069.46 372,680.66 0.00 6,664.61 18,400.00 90.80 321.70 7,015.89 6,967.09 - 1,851.77 - 15,271.04 6,002,148.84 372,619.87 0.00 6,764.17 18,500.00 90.80 321.70 7,014.49 6,965.69 - 1,773.31 - 15,333.01 6,002,228.22 372,559.08 0.00 6,863.74 18,600.00 90.80 321.70 7,013.08 6,964.28 - 1,694.84 - 15,394.99 6,002,307.60 372,498.30 0.00 6,963.30 18,700.00 90.80 321.70 7,011.68 6,962.88 - 1,616.38 - 15,456.97 6,002,386.98 372,437.51 0.00 7,062.86 18,800.00 90.80 321.70 7,010.28 6,961.48 - 1,537.91 - 15,518.95 6,002,466.36 372,376.72 0.00 7,162.42 18,900.00 90.80 321.70 7,008.88 6,960.08 - 1,459.45 - 15,580.92 6,002,545.74 372,315.93 0.00 7,261.98 19,000.00 90.80 321.70 7,007.47 6,958.67 - 1,380.98 - 15,642.90 6,002,625.12 372,255.15 0.00 7,361.55 19,100.00 90.80 321.70 7,006.07 6,957.27 - 1,302.52 - 15,704.88 6,002,704.50 372,194.36 0.00 7,461.11 19,200.00 90.80 321.70 7,004.67 6,955.87 - 1,224.05 - 15,766.86 6,002,783.88 372,133.57 0.00 7,560.67 19,300.00 90.80 321.70 7,003.26 6,954.46 - 1,145.58 - 15,828.83 6,002,863.26 372,072.79 0.00 7,660.23 19,400.00 90.80 321.70 7,001.86 6,953.06 - 1,067.12 - 15,890.81 6,002,942.64 372,012.00 0.00 7,759.79 19,500.00 90.80 321.70 7,000.46 6,951.66 - 988.65 - 15,952.79 6,003,022.02 371,951.21 0.00 7,859.36 19,600.00 90.80 321.70 6,999.05 6,950.25 - 910.19 - 16,014.77 6,003,101.40 371,890.43 0.00 7,958.92 19,700.00 90.80 321.70 6,997.65 6,948.85 - 831.72 - 16,076.74 6,003,180.78 371,829.64 0.00 8,058.48 19,800.00 90.80 321.70 6,996.25 6,947.45 - 753.26 - 16,138.72 6,003,260.16 371,768.85 0.00 8,158.04 19,900.00 90.80 321.70 6,994.84 6,946.04 - 674.79 - 16,200.70 6,003,339.54 371,708.06 0.00 8,257.60 19,993.37 90.80 321.70 6,993.53 6,944.73 - 601.53 - 16,258.57 6,003,413.66 371,651.31 0.00 8,350.57 Start DLS' 1.50 TFO 94.52 - 19,996.64 90.80 321.70 6,993.49 6,944.69 - 598.96 - 16,260.5 6,003,416.25 371,649.32 0.00 8,353.82 20,000.00 90.80 321.75 6,993.44 6,944.64 - 596.33 - 16,262.68 6,003,418.92 371,647.28 1.50 8,357.17 20,100.00 90.68 323.24 6,992.15 6,943.35 - 517.01 - 16,323.55 6,003,499.14 371,587.60 1.50 8,456.85 20,200.00 90.56 324.74 6,991.06 6,942.26 - 436.12 - 16,382.34 6,003,580.89 371,530.04 1.50 8,556.70 20,300.00 90.44 326.23 6,990.19 6,941.39 - 353.73 - 16,439.00 6,003,664.12 371,474.63 1.50 8,656.66 20,400.00 90.32 327.73 6,989.52 6,940.72 - 269.89 - 16,493.49 6,003,748.76 371,421.41 1.50 8,756.65 20,500.00 90.20 329.22 6,989.06 6,940.26 - 184.65 - 16,545.78 6,003,834.77 371,370.41 1.50 8,856.62 20,600.00 90.08 330.72 6,988.81 6,940.01 -98.08 - 16,595.82 6,003,922.08 371,321.68 1.50 8,956.48 1/8/2010 10:23:33AM Page 8 COMPASS 2003.16 Build 69 n 1 "1 a7'°a} r 1 0 • ConocoPhillips Standard Proposal Report Da ' EDM v16 Prod 4 Company. "''' ConocoPhillips(Alaska) Inc TV R ... enca a Referen "!!11:1,11,11,:::,::„ I Plan: CD3-124 (36.3+12.5) @ 48.80ft (Doyon � 1 � 9 ' Projects Western North Slope MD Reference Plan: CD3 -124 (36.3 +12.5) © 48.80ft (Doyon 19 .Sites .4 °,I . CD3 Fjord Pad North Reference:. - , ,, True . Weq, " Plan: CD3 124 Survey'Cakutatiton Method. Minimum Curvature gWe,Hbore. Plan: CD2 -124 si - CD3- 124wp04 Pla S ur ve y -_ Measure Vertical „„ r -- Map Map i l i, e. I :1 Depth In Azimuth Depth TVDss +N /-S . +E1 W Northing Easting 0 V ert Section (ftl (° 't°) (ft) f , (ft) (ft} (ft (ft -6,94000 1 1 i'�� 1��;��i 2 0,606.14 90.08 330.81 6,988.80 6,940.00 -92.72 - 16,598.82 6,003,927.48 371,318.76 1.50 8,962.61 - Start 3863.37'hold at 20606.14 MD - 20,607.29 90.07 330.83 6,988.80 6,940.00 - 91.71 - 16,599.38 6,003,928.49 371,318.22 1.50 8,963.76 CD3 101FWWp02 Mid 20,700.00 90.07 330.83 6,988.68 6,939.88 -10.76 - 16,644.57 6,004,010.10 371,274.25 0.00 9,956.26 20,800.00 90.07 330.83 6,988.55 6,939.75 76.55 - 16,693.31 6,004,098.13 371,226.83 0.00 9,156.03 20,900.00 90.07 330.83 6,988.42 6,939.62 163.87 - 16,742.06 6,004,186.16 371,179.40 0.00 9,255.81 21,000.00 90.07 330.83 6,988.29 6,939.49 251.18 - 16,790.80 6,004,274.19 371,131.98 0.00 9,355.59 21,100.00 90.07 330.83 6,988.16 6,939.36 338.50 - 16,839.55 6,004,362.22 371,084.56 0.00 9,455.36 1 21,200.00 90.07 330.83 6,988.03 6,939.23 425.82 - 16,888.29 6,004,450.25 371,037.13 0.00 9,555.14 21,300.00 90.07 330.83 6,987.90 6,939.10 513.13 - 16,937.03 6,004,538.28 370,989.71 0.00 9,654.92 21,400.00 90.07 330.83 6,987.77 6,938.97 600.45 - 16,985.77 6,004,626.32 370,942.29 0.00 9,754.69 21,500.00 90.07 330.83 6,987.64 6,938.84 687.77 - 17,034.51 6,004,714.35 370,894.87 0.00 9,854.47 21,600.00 90.07 330.83 6,987.52 6,938.72 775.08 - 17,083.26 6,004,802.38 370,847.45 0.00 9,954.25 21,700.00 90.07 330.83 6,987.39 6,938.59 862.40 - 17,132.00 6,004,890.41 370,800.03 0.00 10,054.02 21,800.00 90.07 330.83 6,987.26 6,938.46 949.72 - 17,180.74 6,004,978.44 370,752.61 0.00 10,153.80 21,900.00 90.07 330.83 6,987.13 6,938.33 1,037.04 - 17,229.48 6,005,066.47 370,705.19 0.00 10,253.58 22,000.00 90.07 330.83 6,987.00 6,938.20 1,124.35 - 17,278.22 6,005,154.51 370,657.77 0.00 10,353.35 22,100.00 90.07 330.83 6,986.87 6,938.07 1,211.67 - 17,326.96 6,005,242.54 370,610.35 0.00 10,453.13 22,200.00 90.07 330.83 6,986.74 6,937.94 1,298.99 - 17,375.69 6,005,330.57 370,562.93 0.00 10,552.91 22,300.00 90.07 330.83 6,986.61 6,937.81 1,386.31 - 17,424.43 6,005,418.61 370,515.52 0.00 10,652.68 22,400.00 90.07 330.83 6,986.48 6,937.68 1,473.63 - 17,473.17 6,005,506.64 370,468.10 0.00 10,752.46 22,500.00 90.07 330.83 6,986.35 6,937.55 1,560.95 - 17,521.91 6,005,594.67 370,420.68 0.00 10,852.24 22,600.00 90.07 330.83 6,986.22 6,937.42 1,648.27 - 17,570.65 6,005,682.71 370,373.27 0.00 10,952.01 22,700.00 90.07 330.83 6,986.09 6,937.29 1,735.59 - 17,619.38 6,005,770.74 370,325.85 0.00 11,051.79 22,800.00 90.07 330.83 6,985.96 6,937.16 1,822.91 - 17,668.12 6,005,858.77 370,278.43 0.00 11,151.56 22,900.00 90.07 330.83 6,985.83 6,937.03 1,910.22 - 17,716.86 6,005,946.81 370,231.02 0.00 11,251.34 23,000.00 90.07 330.83 6,985.70 6,936.90 1,997.55 - 17,765.59 6,006,034.84 370,183.60 0.00 11,351.12 23,100.00 90.07 330.83 6,985.57 6,936.77 2,084.87 - 17,814.33 6,006,122.88 370,136.19 0.00 11,450.89 23,200.00 90.07 330.83 6,985.44 6,936.64 2,172.19 - 17,863.06 6,006,210.91 370,088.77 0.00 11,550.67 23,300.00 90.07 330.83 6,985.32 6,936.52 2,259.51 - 17,911.80 6,006,298.95 370,041.36 0.00 11,650.45 23,400.00 90.07 330.83 6,985.19 6,936.39 2,346.83 - 17,960.53 6,006,386.98 369,993.95 0.00 11,750.22 23,500.00 90.07 330.83 6,985.06 6,936.26 2,434.15 - 18,009.26 6,006,475.02 369,946.53 0.00 11,850.00 23,600.00 90.07 330.83 6,984.93 6,936.13 2,521.47 - 18,058.00 6,006,563.05 369,899.12 0.00 11,949.77 23,700.00 90.07 330.83 6,984.80 6,936.00 2,608.79 - 18,106.73 6,006,651.09 369,851.71 0.00 12,049.55 23,800.00 90.07 330.84 6,984.67 6,935.87 2,696.11 - 18,155.46 6,006,739.13 369,804.30 0.00 12,149.33 23,900.00 90.07 330.84 6,984.54 6,935.74 2,783.44 - 18,204.20 6,006,827.16 369,756.88 0.00 12,249.10 24,000.00 90.07 330.84 6,984.41 6,935.61 2,870.76 - 18,252.93 6,006,915.20 369,709.47 0.00 12,348.88 24,100.00 90.07 330.84 6,984.28 6,935.48 2,958.08 - 18,301.66 6,007,003.24 369,662.06 0.00 12,448.65 24,200.00 90.07 330.84 6,984.15 6,935.35 3,045.40 - 18,350.39 6,007,091.27 369,614.65 0.00 12,548.43 24,300.00 90.07 330.84 6,984.02 6,935.22 3,132.73 - 18,399.12 6,007,179.31 369,567.24 0.00 12,648.21 24,400.00 90.07 330.84 6,983.89 6,935.09 3,220.05 - 18,447.85 6,007,267.35 369,519.83 0.00 12,747.98 24,469.51 90.07 330.84 6,983.80 6,935.00 3,280.75 6,007,328.54 369,486.88 0.00 12,817.34 TD at :24469.51 - 4 - 1/2';. x 6 . 1/8/2010 10:23:33AM Page 9 COMPASS 2003.16 Build 69 0 .:-8.,- , i- -.., 1 i • • Conoco Phillips HALL1BURTON Standard Proposal Report Database: '.„ . __-__----, EDM v16 Prod r.:Local bo-ordinati Reference: ' '..: :.,.1 Well Plan: CD3-124 , ii.Company_ _-_-_ ConocoPhillips(Alaska) Inc. ' Reference:. '.i',.,. ' -- -ti -- -.-1,-, ____ , . ' Plan: CD3-124 (36.3+12.5) © 48.80ft (Doyon 19 1 Project:---- Western North Slope - -iMEtRefeience: __-_L:-_,'--_-- :.. ----;___ ' .. Plan: CD3-124 (36.3+12.5) © 48.80ft (Doyon 19 - - i '-'--- -------------- -------'--- ' - - Site: 4 . ':i , CD3 Fjord Pad :','North Referelicitij . -.......,.. -_--_---_ True Well: :_ '',':',' :::....... Plan: CD3-124 - , - Sutvey r dititUtatiotiNiettiod: _-_----_-_-]: Minimum Curvature 1Nellbare: '''."'"!!ifii Plan: CD2-124 .: ..,. itDooign: H- ___. CD3-124wp04 ... ... -..„, Planned Survey ... ---:- HH..:..'' ----------------- " . :".!'!'"_'':.tH. -,---;=.--,-_---_-- .'''';'' -_ _ '---_ :."-_---- ".---------- -_'..'.':'.' - . _.i:,..' _ ' '.'''''''': - ---- -- -------LH"- --- - 11H - :" -- ------ -- _'_ - _ - - -- -_ - _-_ - _ - :_: - .L.;N:_ - _-_ - ,-_'• . ' , ' , 1 - r f _ -- 1 Measured " - _- ----_-----_- '-_- ___-Vertical_- -"'... ----------,------------- ''' ': .' : .-- --------- .' — ----:-: HMep ------- ' ' H.. - ----- -Map_-_-_ .... bePth Inclination Azimuth Depth ,- - - --z-===-_-1VDss.: -----=-_ +NI-S '"',: ' - -+El_,W H... _-_-_NOirthing - _ ---- _:_iEastinff -- t -- F -- . iiiiii:::pl-Si:- ecdItin::,1 (ft) .':iitii: ---_- r) --- --: _-_-__ (-)..::::::: - (ft) ft - :..' (ft} :114- - _- ',:! - - --, =ffIl i::: -_---_- ::..... ifft..1....,.:,.H.::. 8,935.00 ,______::::.:..:...::::.: ............... " • 24,470.69 90.07 330.84 6,983.80 • 6,935.00 3,281.78 -18,482.30 6,007,329.58 369,486.32 0.02 12,818.51 --_ CD3-101FWwpXX Toe . .. . ... ... . .. . ' . . t i l liOt. - - - -- - - - - - - -i- - _ - _ -- -_- .' ,„„, . Target-Menlo. fiittinits target Dir Dip-Anglo- ,Dirt:. - --''!ITVEI-- ,4i.N/••,5---- _ - . - Shape.',:iiii.:L -r_ __ - -_-_-!--- . - - - - .- -- . t -v-r) - ___-_- „..:_.:.,:.. -r) ,--_,,____, _!-,.--„-. (ft),,,,,,„__- . ,..:,:(fti-_-_-,,,,-,-_-_-_ ,-- (ft) --------------_-- -„--,-.,..:: ..:--- (ft),,,:!t:: --„--4--- _----- (ft) :,:. CD3-101FWwpXX Top Nechelik 0.00 0.00 6,993.80 -2,578.80 -14,634.74 6,001,412.40 373,245.13 - plan misses target center by 6.72ft at 17431.57ft MD (6993.78 TVD, -2573.61 N, -14630.46 E) - Point CD3-101FVVwp02 Mid 0.00 0.00 6,988.80 -91.71 -16,599.38 6,003,928.49 371,318.22 - plan hits target center - Point CD3-101FWwpXX Toe 0.00 0.00 6,983.80 3,281.78 -18,482.30 6,007,329.58 369,486.32 - plan hits target center - Point '.. Cailligh:Foinis ...„.,.:.:.:.:..::: _- - -- _::_- _ _.:,.--._ __ _-_-- ___,i- :::------ Measured velitcat H.-,--- H:10...:._-_-_--_-Casiptuz-_1 Hole _ .- --Delith .T: - - -- - __ : '_'_"':':. - . --- -=_ -- 15iainot4V - 10biariitt.2 1- 75i - F"- - ii - ...:.....---- : =------,'..-=-------,=-_------_,- - - -- - - _ - - - ..:;-_-_7- -- - , ...: ., --------_,--- - -_ - --- - - -- -- - -- , ,- - -- ,- -_ - _-_- -- --_ --, _:- . .--,----e- - -- - -.- - -- - : '...:Ii: ". -.--- --- - .--- - ----,----::.:.:..: _-----_-------- ..::.::::..r:7 r) ,,,.::.:...- .__..iv..-_,--.73 --- :-- ,,--_,......, :::....„--_..„..,,,.:. -_-_:___..., 3,624.44 2,500.00 10-3/4" x13-1/2" 10-3i4 1-1r/r 17,431.75 6,993.80 7-5/8" X 9-7/8" 7-5/8 9-7/8 24,469.51 6,983.80 4-1/2" x 6-3/4" 4-1/2 6-3/4 1/8/2010 10:23:33AM Page 10 COMPASS 2003.16 Build 69 r) r) '' I (---; I f\ i... , . , ConocoPhillips HALLIBURTOPJ Standard Proposal Report R eface - -. Database EDM v16 Prod Local Co - ordinate nce: !i Well Plan: CD3 -124 Com ConocoPhillips(Alaska) Inc. 3VD Reference:. Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 Project: Westem North Slope MD Reference: Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fjord Pad .North Reference: True Wald: - Plan: CD3 - 124 Survey Calcutatto Method:: Curvature Neltbom: Plan: CD2 - 124 ' I I `Design: CD3 124wp04 Formations Measured Vertical Vertical = Di .. ,Depth Depth D ep SS "11:111: pip Direction 'iii � Ji � = (ft ft ( ) g( ft) � ` ' Name Lithol� C } � 16,648.79 6,841.80 Top Kuparuk D 3,555.31 2,476.80 C -30 17,078.75 6,938.80 Base Nuiqsut 16,840.31 6,888.80 LCU 7,655.25 3,852.80 K -3 16,337.13 6,753.80 Base HRZ 4,678.62 2,853.80 C -20 16,508.39 6,803.80 K -1 16,818.74 6,883.80 Top Kuparuk C 8,462.73 4,123.80 K -2 Basal 17,391.99 6,988.80 Top Nechelik 12,005.49 5,312.80 Albian 97 8,149.87 4,018.80 K -2 16,840.31 6,888.80 Top Nuiqsut 8,081.34 3,995.80 K -3 Basal 13,417.82 5,786.80 Albian 96 15,842.63 6,598.80 Top HRZ Plan Annotations " pVli Measured Vertical Local Coordinates Depth -Depth +NJ-S ', +Elllt ; ! ., ii ipl i�l ft Eiommerrt 399.70 399.70 II 0.00 0.00 Start Build 1.50 599.79 599.70 -1.79 -4.92 Start Build 2.20 901.80 899.70 -13.16 -36.16 Start DLS 3.50 TFO 7.60 2,639.59 2,169.47 - 271.20 - 1,069.54 Start 12753.42 hold at 2639.59 MD 15,393.01 6,449.70 - 2,965.26 - 12,777.29 Start DLS 2.60 TFO 89.00 15,811.93 6,588.80 - 3,014.59 - 13,168.68 Start DLS 1.50 TFO 80.00 16,370.47 6,763.80 - 2,987.63 - 13,697.88 Start DLS 3.17 TFO 76.07 17,431.75 6,993.80 - 2,573.50 - 14,630.60 Start DLS 2.64 TFO 57.70 17,921.98 7,023.80 - 2,225.38 - 14,972.98 Start Build 1.50 18,055.31 7,021.47 - 2,121.91 - 15,057.04 Start DLS 2.00 TFO 147.75 18,125.96 7,019.74 - 2,066.80 - 15,101.20 Start 1867.41 hold at 18125.96 MD 19,993.37 6,993.53 - 601.53 - 16,258.57 Start DLS 1.50 TFO 94.52 20,606.14 6,988.80 -92.72 - 16,598.82 Start 3863.37 hold at 20606.14 MD 24,469.51 6,983.80 3,280.75 - 18,481.72 TD at 24469.51 1/8/2010 10:23:33AM Page 11 COMPASS 2003.16 Build 69 3 11 11' ,ter li ConocoPhillips(Alaska) Inc. -WNS p � Western North Slope I � I 9 CD3 Fiord Pad a - Plan: CD3 -124 p -:, t Plan: CD2 -124 if 1 h Iu CD3- 124wp04 • ( } �I__' i pA g -L.-. ,1 Sperry dr ' ► rv s r 1 "'� Y '� A. Clearance Summary i " Ai �� Major Risk �,� �� Anticollision Report 6 � I 1 °I it 0' 07 January, 2010 1 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -124 - Plan: CD2 -124 - CD3- 124wp04 1, W ell CoordRange: H eight: 0.00 inates: 6, to : 00 24 3 , 469.51 (36.3 +12.5) ft. @ 4 ,518.17 N, 1easured D,527,947.59E (70(Doyon ° 25' 08.0 19) 9" N, 150° 54' 58.50" W) a "'! I � 1 tum an PlanCD3 -124 M8.80ft epth. 1 i , �' Scan Radius is 2,643.32 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited PI '' , Geodetic Scale Factor Applied ,1111 Version: 2003.16 Build: 69 _- Scan Type: GLOBAL FILTERAPPLIED All wellpaths within 200'+ 100/1000 of reference 0 ^ I Scan Type: 25.00 uY 1 2 Al ■INVdV I L RT N i g 1 imiro Sperry Drilling Services GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16:29, January 07 2010 CO3- 124wp04 Ellipsoid Color 36.30 T 24469.51 36 — 250 1750 2000 5000 — 6000 14000 16000 CD3- 123wp02 ID3- 122wp05 250 500 2000 2500 6000 7000 16000 1800C I 500 750 2500 3000 7000 8000 18000 "— 20000 0 / 360 CD3 121wp02 CD3 120wp02 750 1000 3000 3500 8000 9000 20000 25000 300] 03- 119wp0 1000 1250 3500 -- 4000 9000 _ 10000 n 1 111�j; 6' 1250 1500 4000 4500 10000 12000 - / 330 - I P ` ,133 - 1500 1750 4500 5000 12000 14000 Ta �vt i PD3 -11'- • 201 tgea0- x, �a a 60 / 300 `�, II � + "etr 60 3133- 123wp0e "n ti "41' f "jtts + 133 -11' 0 / 360 i s r' 4 x artt t i I- -30 / 330 r - 30 ' C ,+ ,ak,^ . i a ` , +1'� *,:ti s ., 133 - 11: 4 7 'a t' ,� "� 5' A 0 i p ,ea P *a � 4 � � J , � rm.... t a > ii } � ;i'' x"� p` " 1 "\ i ��" ti 1 1 1 ' D3- 122wp0� �� yu €" S t N�1i� l , f rb CD3 11f x 0 4 4 , eJ l �!� i VORN40—A10.1A, °.� ' i� f r , � � VA �,� 60 / 300 l . 60 t ,�1 zo s 1 il wool 90 / 270 i 7 -, € Al, w5 ,' 1 �► Q,, i any r } .� r _ " '., i, i 4 $ , ' s , - E CD3- 125wp0 r t0 �c �• y � s11 1u1� 'it v ? P � h ■ +y '' 't s � L o ' C D3 316APB 1 u ∎1 �3 �aiin�;° ti �1 °i °; " � 1 1 , l i d ° �1j 11 �� Ikelip a t �I' " � ° x � c ° �w ■ CD3 -.... 90 / 270 ..x� 90 11 ' } FV � i 11 1 ` xi - a ixp�. � � p ulii } x R, �� 5� " I t p � .ail I II Pm �2 � U i t g ,, D3 31E , � g � "QI ►\\ ... I.1— , k / CD3- 126wp02 I � � /jJ��3 � , * It % � 1I - 120 / 240 �I 120 :133 -11 Ow'"'I ® `� 1 - 1 20 / 240 `� � \ \ ' til l %� �� % 1 20 200. �� ift i i - , - ' � 150 / 210 150 150 / 210 -1111111.„,111• , �1 150 303- 125wp0 1 - 180 / 180 300 CD3- 126wp02 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] Easting (3000 ft/in) I I I I I l I l I I l I I l I 1 l l I I I I l I I 1 1 1 I I I l I 1 1 1 1 I I I I I I l I i I 1 1 I I I 1 1 I 11 1 I 1 1 I I I 1 1 I 1 1 1 1 I l l — ConocoPhillips(Alaska) Inc. -WNS CD3- 126wp02_ Western North Slope CD3- 125wp0! CD3 Fiord Pad - = CD3 -112 • CD3 -113 J - CD3 -11 - z — ° a. CD3 -11 - - N � CD3- 124wp04 CD3 -11 _ _ r = CD3 -11 • o - Nigliq A \I S s z_ — 1 Ni..q 1 CD3 -3 i6A CD3 -316 CC-3-3 •' - „woo. CD3 -120w 3- 119wp02 CD3- 121wp02 CD3- 122wp05 Date prepared. ;. - , ry 072010, CD3- 123wp02 - 1�i�'2$ JanuO Easting (3000 Win) ConocoPhillips(Alaska) Inc. -WNS HALLIBURTQN Western North Slope Anticollision Report for Plan: CD3 -124 - CD3- 124wp04 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -124 - Plan: CD2 -124 - CD3- 124wp04 Scan Range: 0.00 to 24,469.51 ft. Measured Depth. Scan Radius is 2,643.32 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 CD3 Fiord Pad • CD3 -112 - CD3 -112 - CD3 -112 587.33 233.50 587.33 221.95 600.00 20.209 Centre Distance Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 610.50 233.82 610.50 221.88 625.00 19.579 Clearance Factor Pass - Major Risk CD3 -113 - CD3 -113 - CD3 -113 148.90 219.26 148.90 216.16 150.00 70.837 Centre Distance Pass - Major Risk -`'` CD3 -113 - CD3 -113 - CD3 -113 446.19 220.25 446.19 210.69 450.00 23.020 Clearance Factor Pass - Major Risk 71 CD3 -114 - CD3 -114 - CD3 -114 398.75 199.43 398.75 190.91 400.00 23.391 Centre Distance Pass - Major Risk - . - - CD3 -114 - CD3 -114 - CD3 -114 493.84 200.47 493.84 189.85 500.00 18.880 Clearance Factor Pass - Major Risk i -... ) CD3 -115 - CD3 -115 - CD3 -115 1,027.10 157.69 1,027.10 136.28 1,075.00 7.364 Centre Distance Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 1,049.67 157.97 1,049.67 136.27 1,100.00 7.278 Clearance Factor Pass - Major Risk CD3 -117 ii003..117 = CD3 117 9,794,42h 9.3,58 "i''';794.42 82.71 1;$,7 C00 3.031 Centre Distance Pass - Major Risk _- CD3 41 « 17 G( 3 -117°- CD3 -117 1,841.79 94.03 1,841.79 62.075 1,925:0Q 2.942 Clearance Factor Pass - Major Risk ..w CD3 =118 CD3-1113? CD3 -118 2,158.63 ,95,79 2158.83 58.2x- 2,250.00 2.552 Centre Distance Pass - Major Risk .. 'CD3 - 118 - C_D3 -118 r,CD34118 2,,467.07 87181 2,467.07 57:13 2,575.00 2.405. Clearance Factor Pass - Major Risk- CD3 -316 - CD3 -316 - CD3 -316 543.29 158.31 543.29 147.04 550.00 14.046 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 591.26 158.82 591.26 146.77 600.00 13.180 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 543.29 158.31 543.29 147.04 550.00 14.046 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 591.26 158.82 591.26 146.77 600.00 13.180 Clearance Factor Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 543.29 158.31 543.29 147.04 550.00 14.046 Centre Distance Pass - Major Risk • CD3 -316 - CD3- 316APB1 - CD3- 316APB1 591.26 158.82 591.26 146.77 600.00 13.180 Clearance Factor Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 224.70 99.86 224.70 95.18 225.00 21.328 Centre Distance Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 448.28 100.84 448.28 91.29 450.00 10.560 Clearance Factor Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 399.69 79.71 399.69 71.23 400.00 9.399 Centre Distance Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 497.64 80.72 497.64 70.10 500.09 7.600 Clearance Factor Pass - Major Risk Plan: CD3 -121 - Plan: CD3 -121 - CD3- 121wp02 424.31 59.71 424.31 50.69 425.00 6.621 Centre Distance Pass - Major Risk Plan: CD3 -121 - Plan: CD3 -121 - CD3- 121wp02 522.70 60.84 522.70 49.67 525.00 5.450 Clearance Factor Pass - Major Risk Plan: CD3 -122 - Plan: CD3 -122 - CD3- 122wp05 374.90 40.07 374.90 32.78 375.00 5.495 Centre Distance Pass - Major Risk PtatrQD3 =122 - Plan :'CQ3 122 - CD3 - 9221005 548,29= 4 ",;1 .53 548.29 30-a8 550','00' 3.898 Clearance Factor ;Pass - Major Risk I? lan:'CD3 -i23 - Plan: COi,3,'k123 CD3= 123Wp02 44944 119,64 449.44 100 454.00 2.054 Centre Distant a Pass . Major Risk: PtaMCD3 123 } Plarl5CD3 -123 CD3423W052 4 73:71 21.43 5M;71:1 8.77 - 575,00, 1.715= Clearance Pass - Major :Rik. 07 January, 2010 - 16 :22 Page 2 of 5 COMPASS 1 ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -124 - CD3- 124wp04 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -124 - Plan: CD2 -124 - CD3- 124wp04 Scan Range: 0.00 to 24,469.51 ft. Measured Depth. Scan Radius is 2,643.32 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 Platt: CD3 -125:- Plan: CD3' -125 - CD3=125wp02, 550,01 18.04; 550.01 6.29, 550.00 1.535= Centre DistanGe Pass - Major Risk ,plan: CD3-125 - Flan: CD3-125 , CD3-1259002 574.97 46:22 574.97 5;93 _575A10 1A82 plan: CD3 -126 ..Plan :' 126 = CD3-126)002 726.69 134.58 726.69 18'.99 725:00 2.2119 Centre Distance s ctr Pass - Major Risk • Pass -Major Risk Plan: CD3 126 , ' Plan; ?CD3 -126 = CD3- 125;wp02 751.53 35,00 751.53 18,87 750.00 2.170 Clearance Factor Pass - Major_Risk WNS Non -Pad Nigliq 1 - Nigliq 1 - Nigliq 1 21,723.11 2,304.70 21,723.11 2,076.21 7,150.00 10.087 Clearance Factor Pass - Major Risk Nigliq 1 - Nigliq 1A - Nigliq 1A 21,520.38 1,828.07 21,520.38 1,648.06 6,975.00 10.155 Centre Distance Pass - Major Risk "` Nigliq 1 - Nigliq 1A - Nigliq 1A 21,529.56 1,829.17 21,529.56 1,646.52 7,050.00 10.015 Clearance Factor Pass - Major Risk Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 36.30 1,000.00 CD3- 124wp04 CB- GYRO -SS 1,000.00 24,469.51 CD3- 124wp04 MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. II 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. 07 January, 2010 - 16:22 Page 3 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTDN Western North Slope Anticollision Report for Plan: CD3 -124 - CD3- 124wp04 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3 -124 (36.3 +12.5) @ 48.80ft (Doyon 19). Northing and Easting are relative to Plan: CD3 -124. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 °, Grid Convergence at Surface is: -0.86 °. Ladder - - - ; — — • ; , $ CD3112,CO3112CO3 112 2250 .P �'_ -- J} I '' ' ' I CD3 -113, 003.113, CD3 -113 V6 - - t Id) Ij 1� } i . 1 I iJ I �� -1- CD3- 114,CD3- 114,CD3- 114V14 r ~` Pi it ♦j 1 ` I 4 , -X- CD3- 115.0O3- 115,CO3 -115V0 "t C - - - , I +I. J . �, '' 41 i II $ CO3.117. CO3.117 , CD3 -1 17 VO O ' 11 . s „.. 1 11 el f y �� -e- CO3 -118. CO3.118. CO3 -118 V0 'n ki ":+ 1500 !'N it r -4-- CO3- 316.003- 316.CD3 -316 VO i 1 1 I -8- CD3- 316,CD3- 316A,CD3- 316AV0 it le r 0 ' J # j+ .... 1 t + � I Pi 1 -B- CD3- 318 ,CD3- 316APB1,0D3- 316APB1 VO . • d F a) -- - il : + I I _ ' - - Plan: CD3- 119,PIan:CD3- 119,CD3.119wpO2 VO C L I j i a f I r+ I I —0— Plan: CD3- 120,PIan:CO3- 120,CO3.120wp02 VO ;r "� _ . !, i 1 -0- Plan : CD3 .121,PIan:CO3- 121,CD3- 1 750 !..r t PIa n: GD3.122,PIan :CO3- 123,003- 123w w r'.1 1 r • . -,ir ,� � .::,,,,, „:,, 1 I Plan: CD3- 123,PIan:CD3- 123,003 -123 O2 VO i . �,�..;;�° I I ' Plan: CD3- 125,PIan:0D3- 125,0D3- 125wp021N CD - - ' r.' r+ �.r��uSwi ` ��L 1 I 1 Plan: CO3- 126, Plan: CO3- 126,003- 126wp02 VO U !.Ii.i. Cam` I I I I I : :.UJ 1 I I 1 I Nigliq 1, Nigliq 1,Nigliq 1 VO I i : ' -A- Nigliq 1,Nigliq 1A.Nigliq 1AVO 0 0 4000 8000 12000 16000 20000 -9- C013124wp04 Measured Depth (4000 ft /in) i 07 January, 2010 - 16:22 Page 4 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -124 - CD3- 124wp04 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 1 iiiiiiiii 1 1 moo I l - . - ` A. ,,1 I I'P &;6 � ai � ';■ I • ., � I ...■ LEGEND ki • ' 41 T ii � , I -0- C D3.112, C D3.112, CD3.112 V3 II ►. �I i 1 Ial $ CD3 -113, CD3- 113,CD3.113 V6 - Iz. l I . 1 I --e- CD3 -114, CD3- 114,CD3- 114V14 2 — i 11 MI t 'U' _ y .... + ` g' ' pirg-t,--- n I . vii I c 9 . j I - CO3 -115, CD3 -115, CD3 -115 VD I � _ 1 + c I e r CO3- 117,CO3- 117,003 -117 V0 6 ` r i l i t ¢ f . c� II_ k . ,,,�r� ri CD3- 118,cD3- 118.CD3 -118UD 1 ' �i _ n• t I : _T H CD3- 316.003.316,CD3316V0 ii • E T D3 318, CD3 316A, CD3 316AV0 " m , .S1 � `� . 1 ; -9— CD3 .316 ,CD3- 316APB1,CD3- 316APB1V0 t � �� ca 1 C , $ Plan: CD3- 110,PIan:CD3- 11g,CD3- 110wp02 VD n cu P15 1 I � t rS e { - Plan: CD3- 120,PIan:CO3- 120,CO3.120wp02VD �� p ',r� la , CO I -e- Plan: CD3 .121,PIan:CD3.121,CD3.121wp02V0 a `� ( .,., .. - ° ..t. ti, mp -Plan: CD3- 122,PIan:CD3- 122,CD3- 122wpD5 V0 R ��; i I -+ a �i.11l ii� $ Plan:CO3.123,Plan:CO3- 123,C 03- 123wp02VD mfr PI CD3 -125 PI •an. an. �4 ' CD3 125 CD3- 125wpD2 VD ` IMINIII u 1 I ' , f -- Plan: CO3- 126,PIan:CD3- 126,CD 126wp02 VD III 1 U M E NEMI♦HI■ ■1■iNU ■■■tUU■■■UUI111.i1 tiU■■U!#UI■■ IUII■ -- N igli q 1 , N igli q 1 , N igli q 1 V D 1 , I 4- Nigliq 1, Nigliq 1A, Nigliq 1A VD 3 .' 6 ,, - 44 - .' I gg � I � 4 �„ I l _� i ' � F { ...' -13- CD3 124wpD4 { -' j fl u J p 111 MO i 1 I I fir I i i i i 1 1 11 I 1 f i f e .. 0 MOO MO MOO WOO IO1000 1310 14000 18003 MOO 33030 M300 3100011 Measured Depth (4000 ft4n) 07 January, 2010 - 16.22 Page 5 of 5 COMPASS I GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16:30, January 07 2010 CD3- 124wp04 Ellipsoid Color 36.30 To 500.00 36 250 1750 — 2000 5000 6000 14000 16000 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 — — 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 _ 4000 9000 _ 10000 1250 1500 4000 4500 10000 12000 P 30 1500 1750 4500 5000 12000 14000 201 -60 60 0 / 360 50 ill 30 10, 123w s, a � D3 ,�� p � Jil�li ° -60 / 60 e$ ,,, - BB3 -316• ..._a . y 122wp0' .. .1 -90 / 270 A _ , i 90 ` wp v, lok ,-.. (( 71,& 1: - ( --- ) ,Ec - 126wp0 ' -90 / 270 re, 90 0 11 /'-- — ' i iii, 25wp0 -120 / 240 120 • -120 / 240%' -126wp0 . 120 200 - 150/210 150 -150 /210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16:31, January 07 2010 CD3- 124wp04 Ellipsoid Color 500.00 To 1000.00 36 250 1750 — 2000 5000 - 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 18000 500 750 2500 3000 7000 8000 18000 " " " " " "" " " " " " "` 20000 0 / 360 750 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 — 4000 9000 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 1750 4500 5000 12000 14000 201 i D3 -119wp D3 -11- CD3- 120wp02, -60 / 300 CD3-122 , 15 ) 60 :D3- 123wp0: r - - 0 / 360 D3-1 :>f f ,, D3-11' 59 23- 123wp0. - �'•q 6 ' 30 / 330 30 � 10101- , 0 _�,� 203 -114 �`�� h x.l5�; i , 1.,�� CD3-122wp0° * �< c - fl % ®r, 60 / 300 d � :( e �s� I. 0 90 / 270 /� i .. ,, V ' '',, 4 I ∎ B 1 � 311 ''''''' %41 D3-11-/ U/ 90 -90 / 270 0 1 s o CD3- 126wp02 -120 / 240 120 t , 41 1 4 4 0,49011 -120 / 240 ��u:� 01%1 120 • 201 AtimWerialit" , ',16 i ftping "p , . 2D3- 125wp0: ■ -150 / 210 �>•� �., 150 -150 /214 150 50 300 -180 / 180 CD3- 126wp0's -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16 :31, January 07 2010 CD3- 124wp04 Ellipsoid Color 1000.00 To 1500.00 36 — 250 1750 2000 5000 — 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 I D3 -1212. ��'122G�05120wp02 750 1000 3000 3500 8000 9000 20000 - 25000 300 1000 1250 3500 4000 9000 10000 Y - CD3- 119wp02 :v O 1250 1500 4000 4500 10000 12000 - / 330 D3 - 123 u1 30 1500 1750 4500 5000 12000 14000 0 C D3 -11L • 20 • firtoszImp.v ‘, wei.N 60 / 300 • r ; y z: ”,, 1' � � 60 11 z ( wJ t A 3 °, 3 0 / 360 PIRIS r r ' ' , 441 ,1 A 40:-- * 4x / r ` 30 / 330 30 r It , sue =,� ;D3 -11: ^^ 4 D3 -11f 60 / 300 60 >•,, -90 / 270 _ D3 -11 90CD3- 125wp0$ /j CD3- 316AP61 ( r � �! �i' _ ,.y� * I 2 -316A Allk „ w ^ ` :D3 -314 -90 / 270 90 0 CD3- 126wp02 -120 / 240 120 - 120 / 240 120 IIII 200 -150 /210 IF 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference 16:32, January 07 2010 CD3- 124wp04 Ellipsoid Color 1500.00 To 2000.00 36 250 1750 2000 5000 - -. 6000 14000 1600C D3 - 123wp02 CD3 122wp05 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 " 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 25000 300 „ , : 0. 1000 1250 3500 4000 9000 — 10000 1250 1500 4000 4500 10000 12000 - 30/ 330 1 iI 30 1500 1750 4500 5000 12000 14000 D3 -11L 20 „ n , 4 1 1,,;‘, so -60 / 300 �. - � !% n, 4 _ 0 / 360 50 t I , -30 / 330 30 16s 1 ati si,ii�9 k, `. ' `¢ 3 ° 2D3 -11 -60 / 300 60 r -90 / 270 0 90 II _ D3 - 11 -- - =: -90 / 270 90 0 11 I -120 / 240 120 - 120/240 120 • _200 -150 / 210 150 - 150/216 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference 16:32, January 07 2010 CD3- 124wp04 Ellipsoid Color 2000.00 To 3000.00 36 250 1750 - 2000 5000 6000 14000 16000 250 500 2000 " " " " "" 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 " °" 2000C 0 / 360 750 — "- 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 1750 4500 5000 12000 14000 20r • 60 / 300 ! ' I fr 4( +' � 60 1 l Tett � `�` , D3 -11f. 0 / 360 � �� -30 / 330 50 30 1 0 . 1,(4.--- ,, \ � \\\ ll , �. :/ ' -60 / 300 60 ,,, ; ;t, '�J) , , - , .� _90 / 270 � ' t t ii ii�ii�I /q D3 -11: 90 1.: j';+ . \ L'D3 -117 90 / 270 90 0 ‘ li 101 _ ' ,--_ _ "'‘j)///1)))) 1 Ily -120 /240 120 -120 / 2 40 120 • 200 - 150 /210 150 -150 /211 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16:33, January 07 2010 CD3- 124wp04 Ellipsoid Color 3000.00 To 4000.00 36 250 1750 2000 5000 —_.. 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 20000 0 / 360 750 1000 3000 3500 8000 9000 20000 – 25000 300 1000 1250 3500 -- 4000 9000 - 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 1•• '-----`,4z `'o / 30/330 30 I i 1` ` \ 'IA t` -60 / 300 60 /Ilk, 90 / 270 �o! „�{, r ;D3 -11 \ Jf ii i ri 1ti r.y444 ,,,z,11 �\lt�� 11 41414 -90 / 270 90 i, o l '', L 7 l s ,_) ,: ) ,1 ,' ,,,, ,I , ' I l l i l ') / I''' - - t D3-114 -120 / 240 ' 120 • ,�V��.I�IVIh��iiiu +l' 120 / 240 120 200 -150 /210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [O] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16:33, January 07 2010 CD3- 124wp04 Ellipsoid Color 4000.00 To 6000.00 36 250 1750 - - 2000 5000 — - 6000 14000 16000 250 500 2000 - -- - 2500 6000 7000 16000 18000 500 750 2500 3000 7000 8000 18000 "'° 20000 0 / 360 750 1000 3000 3500 8000 9000 20000 - 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 'r„ 50 g -30 / 330 30 1 l 1i, 4 � *0 ` * -60 / 300 60 _ w�. _90/ 270 111:11' � 't j90 03 -11E 1 1 \ ``'1 1 11 iii , �\ 90 / 270 90 1 ,,, , .. _____ _ � �� 120 D3 -117 ., 0 120 / 240 , '�� ( , -120 / 240 120 • 200 - 150/210 150 -150 /216 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000, of reference 16 :34, January 07 2010 CD3- 124wp04 Ellipsoid Color 6000.00 To 10000.00 36 — 250 1750 — 2000 5000 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 18000 500 750 2500 3000 7000 8000 18000 — 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 4000 9000 — 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 50 -30 / 330 30 '" l -60 / 300 60 J.. / 270 ;� i , t° "�[ 90 ., 0 ,il ' II (GAY yh / '' Al ,,...„, `a C d" —90 / 270 90 120 I �i�� ( h�, 120 -120 / 240 120 • 200 r, � 150/210 150 150 50 300 -180 / 180 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 16:35, January 07 2010 CD3- 124wp04 Ellipsoid Color 10000.00 To 24469.51 36 250 1750 2000 5000 6000 14000 1600C 250 500 2000 — _ 2500 6000 7000 16000 18000 O 500 750 2500 3000 7000 8000 18000 - 20000 0 / 360 750 -- 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 1750 4500 5000 12000 14000 201 • -60 / 300 60 0 / 360 50 ai -30 / 330 30 .._ -60 / 300 60 . -90 / 270 90 --,li MI' -90 / 270 90 -120 / 240 120 -120 /240 41111F 120 ilIl 200 -150 / 210 150 -150 / 211 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Conoco Phillips CD3 124wp04 Name CD3- 101FWwpXX Toe TVDSS +N/ -S +E / -W Northin Eating Shape 6935.00 3260.04 - 1846269 Point HALLIBLtRTO1V CD3- 101FWwpXX Toe Circle 6935.00 3280.04 - 18482.69 Circle (Radius: 1320.00) Quarter Mlle View CD3- 1 O1FWwp02 Mid 6940.00 X 80 . 16 16599.49 Point Sperry Drilling CD3- 101FWwpXX Top Nechelik 6945.00 - 2580.16 - 14634.63 Point CD3- 101FWwpXX Top Nechelik Circle 6945.00 - 2580.16 - 14634.63 Code (Radius: 1320.00) • 16:45, January 07 2010 GO GOB, G� my 1 6000 _ _- 4,y I Q g G 0o' 4000 co =p � �� . __ � C \ 1 70 °0 2000 \b.- -..li■ livi lk L t.-s.'''' Z 0 1 �D C y CO - - 2000 � � - - 4000 -20000 -18000 -16000 -14000 -12000 -10000 -8000 -6000 -4000 West( -) /East( +) (2000 ft /in) Operator. CorwcoPMps(AbkmOC. -W818 GadCor1ecibn: -086 • AWN* 8N /A Hold VAMern NorthSbpe Magnelb DecImtbn. 2138 • AM No: 881/A *80 CD3- 12dwp04 000 8038 APING: 88 /A Blp PN /A Dey.Bper IDD 1 System (IV 0) 28091011818 MemSea Love Surface beat. OrIgind VS Plane: 327.90 • Puentwdx Mot CO3-124 X 152794789 ft View VS Plane: 327.00 • 288 MOIL 48.50 r V 6003518.17 ft Unit System: APInce84 /05 Section NS) 8eMence: 5104 Comments: POOL: o n Vie 8 8 8 8 S o o ! Lo CD3- 124wp04 Plan: 17431' to 24469.51' MD ._ ,_ 6009000 CD3 -117: 15635' to 21597' MD Nigliq 1: 6900' to 7000' TVDss 6008000 Nigliq 1A: 6900' to 7000' TVDss ___— ...... .__- 5 = _..... , .:1__ - ______ __.. - ._..________— _ -_____ __..- 6007000 i ..< ......_ ___ — ___ -- — _ . _ . _ . _ 6006000 • 0 ____ ___ ......... 1111 - 6005000 • 0 z _ __.___ ......_ . 6004000 . -- Section View — CD3-124wp04 Plan —CD3 -117 �Nlg[q 1 Nigliq 1A .. ........ ....._ _ -_____ _6003000 Cm 1 - ..... .... ::::: . _.____ _._..........._.... • . 6000000 5999000 L 1 N 1 East ( +) / West ( - 1 1 i .- N • 1 N 2 E 0 rn III _._..�. ,,... ._._..........._..._ ........ ..........__.............._...� _..__ - 7100 Vert loci Section long 'View VS Plane" Combo Preview Page 1 of 1 (CD3- 124wp04Toolbox)ds) 1/8/2010 9:49 AM Closest in POOL Closest Approach: Reference Well: CD3- 124wp04 Plan Offset Well: Nigliq 1 - Coords. - Coords. - ASP ASP 3 -D ctr -ctr I „- ; 1 I'■ubr,1 Meas. Incl. TRUE Subsea N( + )/S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. I'- i,,,.,1 CI:I;,:rn,li. Depth Angle Azi. TVD E( +) /W(- (327) Comments Depth Angle Azi. TVD E( +) /W(- (327) Comments POOL Min POOL Min Distance (2299.91 Distance (2299.91 ft) in POOL (17431 ft) in POOL (17431 - 24469.51 MD) to • - 24469.51 MD) to CD3- 124wp04 Plan Nigliq 1 (6900 - (6900 - 7000 • 2299.9 " 21725 90.07 330.83 6938.79 10078.59 7000 TVDss) 7154.23 0.51 124.08 6946.59 - _ 1130.7 TVDss) CD Closest Approach: Reference Well: CD3- 124wp04 Plan Offset Well: CD3 -117 Coords. - Coords. - �' ASP ASP ', ...r ... -,x W 3 -D ctr -ctr ,er�ia,J _ Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS _ Distance. : l�uu � _� � Depth Angle Azi. TVD E( +) /W(- (327) .;omments Depth Angle Azi. TVD E( + ) /W(- (327) Comments T PUUL Mn ' NUUL Min .... Distance (2440.83 Distance (2440.83 ft) in POOL (17431 ft) in POOL (17431 e", ' - 24469.51 MD) to - 24469.51 MD) to CD3 -117 (15635 - CD3- 124wp04 Plan 2440.8 ' 7 ,■:1 !'li,r'r ' 17431.75 83 310 6945.008 - _ 5809.808 21597 MD) 16130 91.76 328.17 6921.04 _ - 5803.78 (15635 - 21597 MD) Closest Approach: Reference Well: CD3- 124wp04 Plan Offset Well: Nigliq 1A . Coords. - Coords. - ASP ASP 3- Dctr -ctr I :-• „n , -I i., 111r•,,, Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. i_ st,,,I I 'HItiaro Depth Angle Azi. TVD E( +) /W(- (327) Comments Depth Angle Azi. TVD E( +) /W(- (327) Comments 0 PUUL min . POOL Min Distance (2951.96 Distance (2951.96 ft) in POOL (17431 ft) in POOL (17431 - 24469.51 MD) to ' - 24469.51 MD) to CD3- 124wp04 Plan Nigliq 1A (6900 - (6900 - 7000 2952 = __ . 1 1 i II r . - ' _ 21800 90.07 330.83 6938.695 _ _ 10153.42 7000 TVDss) 9357 54.45 51.77 6887.69 _ MINN 874.69 TVDss) PoolSummary1 1/8/2010 9:57 AM 0 1 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 4/8/07 AG DB C.A. UPDATED PER K07041ACS 6 4/13/09 AG DB C.A. UPDATED PER K090003ACS N °R. -R� LLSI-E .D- �� \Of ► -0. Lc ,tom __ millil rP „...„ . ii r aro- M O a III , P Al ,„,„,.. 11.4 r_ ,,, ...,,- . V. --. iiii � :. , ' l .„/"..,„ LOCATION OF � ti 11,40,1_, THIS SURVEY ^v. R / �l OM x Ti 1N "� J � ALPINE SATELLITE DEVELOPMENT "� ��" a VICINITY MAP NOT TO SCALE 1 p A0 pES1GN SHOl1�0ER OF CD-3 PAD \ , y , n ,., CN F NR0 ipt- �Q° -- -` :-- ^ _•� i� • • • ' ECM S' v • 2 - R N N % N,n B I • 2- ., �� 01-E 2 = �i - sow � ••• •• PRHEATER N �' �D F � 6 , 00 510RP WD * O WPRENOOSE S PLANT ► ASPC a T ERS N 13'00'00" w w N LEGEND: 0 0202 O PROPOSED CONDUCTOR -o w � ° Cs! _ N I t , — �w oA to • EXISTING CONDUCTOR V ° \ O rn 0 =p O 0 KUUKPIK U U N N O LCMF � But tie 0111. ..• NMoay. Nariecew (907)2734••• A pia. omw Ilan 8]0a]39 Alpine Survey Office ALPINE MODULE: CD30 UNIT: CD Conoc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03 -03 -1A 11 /3/05 CE -CD30 -111 1 OF 3 6 • REV DATE BY CK APP DESCRIPTION REV DATE BY C APP DESCRIPTION 6 4/8/07 AG DB C.A. ISSUED PER K07041ACS 7 4/13/09 AG DB C.A. UPDATED PER K090003ACS NAD 83 • ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CO3 -X98 6,003,630.37 1,528,434.35 70' 25' 09.267" 150' 54' 44.278" 1392' 642' 7.3 2.5 CO3 X99 6,003,625.99 1,528,415.38 70° 25' 09.221" 150° 54' 44.833" 1387' 661' 7.3 2.8 CD3 -301 6.003.621.33 1.528.395.58 70' 25' 09.172" 150' 54' 45.411" 1387' 680' 7.3 3.5 CD3 -302 6,003,616.72 1,528,376.38 70' 25' 09.124" _150' 54' 45.972" 1377' 700' 7.3 3.2 CD3 -303 6,003,612.52 1,528,356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 3.3 CO3 -304 6,003,607.82 1,528,337.04 70' 25' 09.031" 150' 54' 47.122" 1368' 739' 7.3 3.4 003 -305 6,003,603.48 1,528.317.56 70' 25' 08.985" 150' 54' 47.691" 1363' 758' 7.3 3.6 CD3 -106 6,003,599.43 1,528,298.37 70' 25' 08.942" 150' 54' 48.252" 1359' 777' 7.3 3.4 CD3 -107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150' 54' 48.820" 1354' 797' 7.3 3.2 0D3 -108 6,003,589.85 1,528,259.61 70° 25' 08.842" 150° 54' 49.385" 1349' 816' 7.3 3.1 003 -109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54' 49.962" 1344' 836' 7.3 3.1 CO3 -110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150' 54' 50.533" 1339' 855' 7.3 3.0 CO3 -111 6,003,576.13 1,528,201.08 , 70' 25' 08.699" _ 150' 54' 51.095" 1334' 874' 7.3 2.9 CD3 -112 6,003,572.43 1,528,181.20 _ 70' 25' 08.660" 150° 54' 51.676" 1330' 894' 7.3 3.1 CD3 -113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150' 54' 52.255" 1325' 914' 7.3 3.1 CD3 -114 6,003,563.04 1,528,142.21 70° 25' 08.561" 150' 54' 52.815" 1320' 933' 7.3 3.3 CD3 -115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150' 54' 53.388" 1315' 953' 7.3 3.7 CD3 -116 6,003,554.04 1,528,103.39 70' 25' 08.467" 150° 54' 53.950" 1311' 972' 7.3 3.2 0D3 -117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54' 54.516" 1306' 991' 7.3 31 CD3 -X18 6,003,544.88 1,528,064.44 70° 25' 08.372" 150° 54' 55.086" 1301' 1011' 7.3 2.8 CD3 -X19 6,003,540.17 1,528,044.86 70' 25' 08.322" 150' 54' 55.660" 1796' 1030' 7.3 2.8 CD3 -X20 6,003.535.95 1,528,025.39 70' 25' 08.278" 150° 54' 56.229" 1991' 1 50' 7.3 2.6 CD3 -X21 6,003,531.41 1.528.006.04 70' 25' 08.230" 150' 54' 56.794" 1986' 69' 7.3 2.5 CO3 -X22 6,003,527.00 1,527,986.67 70' 25' 08.184" ' 150° 54' 57.360" 1282' 1088' 7.3 2.6 CD3 -X23 6,003,522.43 1,527,967.12 70' 25' 08.136" 150' 54' 57.932" 1777' 1108' 7.3 2.6 CD3 -X24 8.003.518.17 1.527.947 59 70' 75' 08 091" 150' 54' 58.502" 1979' 1127' 7.3 7 5 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4,I NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B. .M.S.L.) y/ ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -2 3 -17 -05 CE -CD30 -111 2 OF 3 7 \ i, 4 5 .. :7 ..,.. REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 4 4/8/07 AG DB C.A. ISSUED PER K07041ACS 5 4/13/09 AG DB C.A. UPDATED PER K090003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD -3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK /LCMF, MARCH 2005 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD3 -108, CD3 -109, CD3 -110, CD3 -111, 3/16/05, FB 2005 -08 PGS 52 -53; CD3 -301, CD3 -302, 3/19/05, FB 2005 -09 PGS. 24 -25; CD3 -304, 4/16/05, FB 2005 -12 PGS 35 -37. CD3 -303 2/10/06, FB 2006 -03 PG 11. CD3 -112, 2/23/06, FB 2006 -05 PGS 29 -31. CD3 -107, 3/26/06, FB 2006 -09, PGS.9,25 -27. CD3 -305, CD3 -106, CD3 -113, CD3 -114, CD3 -115, CD3 -116, CD3 -117, 5/2/06, FB 2006 -11 PGS 57 -61; CD3 -X18, 4/7/07, FB 2007 -07 PG. 67; CD3 -X98, CDX -99, CD3 -X19, CD3 -X20, CD3 -X21, CD3 -X22, CD3 -X23, CD3 -X24, 4/13/09, FB 2009.05 PGS. 70 -72. SURVEYOR'S CERTIFICATE 67*�� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED O T PRACTICE � . P� ••� • ASS- BUIILT REP ES MADE BYEMEEFOR ALASKA, THAT THIS UNDER MY DIRECT • ;:' ' •. 1 SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST '•• ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE ' 49th /‘ • * , CORRECT. • / DATE: REGISTRATION NO. LS -5077 A . Donald G. Bruce 3 a ♦♦ p� % No. LS -5077 •,•'•��` • 'Pe '••• ............. . ••''• KU U KP I K N ot4 M- ' ,� L 1W LIiEAw • AMwnp�,AWW fl07 AWne Oiflre (90 Alpine Survey Office ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -3 3 -17 -05 CE -.CD30 -111 3 OF 3 5 IN IN, rN r , fl , • • TRANSMITTAL LETTER CHECKLIST WELL NAME Colville River Unit CD3 -124 PTD# 2100080 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: COLVILLE RIVER POOL: FIORD OIL POOL 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 , Permit No. (If last two digits in API No. . Production should API number are continue to be reported as a function of the original API number between 60 -69) stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, 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 through target 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 (Company 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 such water well testing program. Rev: 1/11/2008 D,t r �: i -Field & Pool COLVILLE RIVER, FIORD OIL - 120120 Well Name: COLVILLE RIV FIORD CD3- 124 Program SER Well bore seg PTD#: 2100080 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type SER / PEND GeoArea 890 Unit 50360 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 372105, top prod interval in ADL0025526, TD in ADL 380092. 3 Unique well name and number Yes 1 Well located in a defined pool Yes COLVILLE RIVER, FIORD OIL - 120120, governed by CO 569. 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 569 has no interwell spacing restrictions. 1 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes external property line where ownership or landownership changes. 9 Operator only affected party - Yes 110 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 1/19/2010 1 • 4 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes A10 30, issued July 25, 2006 15 All wells within 1/4 mile area of review identified (For service well only) Yes None (Niqliq 1 is —2400' away at the top of the Nechelik) 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) Yes Well will be pre - produced for 3 to 6 months. 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j,2.A -D) NA 1 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers... 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC in 7 5/8" at 15500' MD. 22 CMT will cover all known productive horizons Yes Qannik interval covered with second stage cement. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 126 Adequate wellbore separation proposed Yes Proximity analysis performed. All wells pass major risk. 27 If diverter required, does it meet regulations NA Waiver requested for no diverter granted. No shallow gas issues in CRU. 20 AAC 25.035 (h)(2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3160 psi ( 8.7 ppg EMW) Will drill with 9.3 ppg mud GLS 1/19/2010 129 BOPEs, do they meet regulation Yes 1 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2463 psi Will test BOP to 3500 psi OI 31 Choke manifold complies w /API RP -53 (May 84) Yes - 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S not likely but rig has sensors and alarms. I34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR completed ...no issues with wells in 1/4 mile. 35 Permit can be issued w/o hydrogen sulfide measures Yes H2S not encountered in offset wells. However, rig will be equipped with operational sensors. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.7 ppg EMW; will be drilled with 9.0 - 9.3 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA None expected based on numerous wells drilled from CD3 -Pad SFD 1/19/2010 38 Seabed condition survey (if off - shore) NA 1 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Pub;,. Date: Date Date Commissioner: Co issioner Co w +• -r /-20--/e /-?•d• • • Well History File APPENDX 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. 4111 4111 Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 11 16:11:04 2010 Reel Header Service name LISTPE Date 10/03/11 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 10/03/11 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD /MAD LOGS # I WELL NAME: CD3 -124 API NUMBER: 501032061200 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 11- MAR -10 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: -MW- 0006991484 -MW- 0006991484 LOGGING ENGINEER: J. BOBBITT J. BOBBITT OPERATOR WITNESS: D. BURLEY F. HERBERT SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 4008 FSL: FEL: 1127 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 49.29 GROUND LEVEL: 12.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3540.0 2ND STRING 6.750 7:25 17888.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). ONLY INVERT /REVERT INTERVALS GREATER THAN 30' TVT ARE INCLUDED ON TVD PLOTS. 3. MWD RUN 1 COMPRISED DIRECTIONAL AND AT -BIT INCLINATION (ABI) WITH ELECTROMAGNETIC WAVE TELEMETRY (EM) - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -P4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), AND GEOPILOT ROTARY - STEERABLE BHA (GP). MWD RUN 2 ALSO INCLUDED ACOUSTIC CALIPER (ACAL). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIRE- MENTS AT CONOCO- PHILLIPS /VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1 -3 REPRESENT WELL CD3 -124 WITH API #: 50 -103- 20612 -00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 23, 981'MD/7003'TVD. SROP = RATE OF PENETRATION WHILE DRILLING. SGRC = DUAL GAMMA RAY COMBINED. SEXP = EWR PHASE -4 9" 2 MHZ PHASE SHIFT RESISTIVITY. SESP = EWR PHASE -4 15" 2 MHZ PHASE SHIFT RESISTIVITY. SEMP = EWR PHASE -4 27" 2 MHZ PHASE SHIFT RESISTIVITY. SEDP = EWR PHASE -4 39" 1 MHZ PHASE SHIFT RESISTIVITY. SFXE = FORMATION EXPOSURE TIME EWR - PHASE -4. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. 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 10/03/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. lb qlIl DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3513.0 23932.0 RPS 3530.0 23939.0 FET 3530.0 23939.0 RPM 3530.0 23939.0 RPD 3530.0 23939.0 RPX 3530.0 23939.0 GR 3545.5 17895.0 ROP 3550.5 23981.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3513.0 17900.0 MWD 3 17900.0 23981.0 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 .1IN 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 GR MWD API 4 1 68 4 2 RPD MWD OHMM 4 1 68 8 3 RPM "`MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 FET MWD HR 4 1 68 24 7 GR MWD API 4 1 68 28 8 ROP MWD FPH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3513 23981 13747 40937 3513 23981 GR MWD API 28.27 1238.4 154.981 5397 3545.5 17895 RPD MWD OHMM 0.25 2000 10.8589 40761 3530 23939 RPM MWD OHMM 0.18 1803.15 9.1494 40761 3530 23939 RPS MWD OHMM 0.29 2000 8.43583 40761 3530 23939 RPX MWD OHMM 0.25 1652.29 7.36526 40761 3530 23939 FET MWD HR 0.21 263.15 1.13955 40761 3530 23939 GR MWD API 23.51 422.93 95.0983 40839 3513 23932 ROP MWD FPH 0.98 323.55 155.913 40862 3550.5 23981 First Reading For Entire File 3513 4111 4111 Last Reading For Entire File 23981 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/11 Maximum Physical Record 65535 File Type LO 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 10/03/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.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 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3513.0 17895.0 SFXE 3530.0 17846.0 SEXP 3530.0 17846.0 SESP 3530.0 17846.0 SEMP 3530.0 17846.0 SEDP 3530.0 17846.0 ABGT 3545.5 17895.0 SROP 3550.5 17900.0 LOG HEADER DATA DATE LOGGED: 17- FEB -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 17900.0 TOP LOG INTERVAL (FT): 3550.0 BOTTOM LOG INTERVAL (FT): 17900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.8 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 216787 ABGT At -Bit Dual GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 0 DRILLER'S CASING DEPTH (FT): 3540.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): - 9.80 MUD VISCOSITY (S): 37.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.650 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .730 166.0 MUD FILTRATE AT MT: 1.500 70.0 MUD CAKE AT MT: 1.550 70.0 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 Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN I 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 GR MWD020 API 4 1 68 4 2 RPD MWD020 OHMM 4 1 68 8 3 RPM MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPX MWD020 OHMM 4 1 68 20 6 FET - MWD020 HR 4 1 68 24 7 GR MWD020 API 4 1 68 28 8 ROP MWD020 FPH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3513 17900 10706.5 28775 3513 17900 GR MWD020 API 28.27 1238.4 154.981 5397 3545.5 17895 RPD MWD020 OHMM 0.25 2000 8.72317 28633 3530 17846 RPM MWD020 OHMM 0.18 1803.15 6.93794 28633 3530 17846 RPS MWD020 OHMM 0.66 77.09 6.1657 28633 3530 17846 RPX MWD020 OHMM 0.97 34.92 5.76533 28633 3530 17846 FET MWD020 HR 0.21 176.08 0.83012 28633 3530 17846 GR MWD020 API 28.27 422.93 117.176 28765 3513 17895 ROP MWD020 FPH 3.68 323.53 186.337 28700 3550.5 17900 First Reading For Entire File ""3513 Last Reading For Entire File 17900 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/11 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 10/03/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SESP 17875.5 23939.0 SEDP 17875.5 23939.0 SFXE 17875.5 23939.0 SEMP 17875.5 23939.0 SEXP 17875.5 23939.0 SGRC 17895.5 23932.0 SROP 17900.5 23981.0 LOG HEADER DATA DATE LOGGED: 05- MAR -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite °--DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 23981.0 TOP LOG INTERVAL (FT): 17900.0 BOTTOM LOG INTERVAL (FT): 23981.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.7 MAXIMUM ANGLE: 93.4 # I TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 241701 EWR4 Electromag Resis. 4 223559 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 17888.0 # " BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.00 f ,- 4111 4111 MUD VISCOSITY (S): 45.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) , MUD AT MEASURED TEMPERATURE (MT): .280 76.2 MUD AT MAX CIRCULATING TERMPERATURE: .130 166.1 MUD FILTRATE AT MT: .160 76.2 MUD CAKE AT MT: .280 76.2 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 Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 1 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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 --- First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 17875.5 23981 20928.3 12212 17875.5 23981 RPD MWD030 OHMM 6.03 1768.13 15.9013 12128 17875.5 23939 RPM MWD030 OHMM 0.33 1468.96 14.3704 12128 17875.5 23939 RPS MWD030 OHMM 0.29 2000 13.7954 12128 17875.5 23939 RPX MWD030 OHMM 0.25 1652.29 11.1425 12128 17875.5 23939 FET MWD030 HR 0.36 263.15 1.87007 12128 17875.5 23939 GR MWD030 API 23.51 145,53 42.4995 12074 17895.5 23932 ROP MWD030 FPH 0.98 268.49 84.1179 12162 17900.5 23981 First Reading For Entire File 17875.5 Last Reading For Entire File 2 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 .:,- Date of Generation 10/03/11 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 10/03/11 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 10/03/11 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF - Physical EOF End Of LIS File