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Home My WebLink About185-080 7Th 18Como Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> )C.-12-1 /fin Sent: Tuesday, December 29, 2015 3:26 PM 1 ! (� To: Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA);Ted Kramer; Alaska NS - Milne - Field Foreman Subject: Shut-In Injector MPB-12 (PTD # 1850800) Due for AOGCC MIT-IA All, Long term shut-in water injector MPB-12 (PTD# 1850800) is due for an AOGCC MIT-IA on 1/7/2016. The well will not be brought online in time for the test and is expected to remain SI for reservoir management.The well will be added to the Quarterly LTSI Injector Report. Thank You, Wyatt Rivard 1 Well Integrity Engineer 0: (907) 777M547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 iii ktrp ,11: < I Imal.-~:>roject Well History File· Cover~dge 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. '1 ~'2 .':] - Q ~) Q Well History File Identifier Organizing (done) RESCAN rnI Two-Sided o Rescan Needed DIGITAL DATA OVERSIZED (Scannable) o Color items: o Diskettes, No. o Maps: o Grayscale items: o Other, No/Type o Other items scannable by large scanner o Poor Quality Originals: , , OVERSIZED (Non-Scannable) o Other: o Logs of various kinds NOTES: o Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanning Preparation ,-3 x 30 = qo + /Õ = TOTAL PAGES /Oc) BY: BEVERLY ø VINCENT SHERYL MARIA LOWELL DATE:IO I~A [/¡JSI ~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: 101 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _ YES ~ NO BY: BEVERLY BREN VINCENT SHERyGR0 LOWELL DATE: 10/3, ItJ'YSI VLtf Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO BY: BEVERLY @VINCENT SHERYL MARIA LOWELL DATE:lO{SL(Ú2/S1 ~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (individual page [special attention) scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) III ~ -III 1 Of25102Rev3NOTScanned. wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 11, 2012 TO: Jim Regg 1 r( ( P.I. Supervisor 7 2 ! SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B -12 FROM: Chuck Scheve MILNE PT iJNIT KR B -12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ; )8f--- NON CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR B -12 API Well Number: 50- 029 - 21338 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS120108081952 Permit Number: 185 -080 -0 : 1/7/2012 Inspection Date: Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-12 - Type Inj. W TVD 7005 - IA 420 2130 ' 2100 2100 P.T.D 1850800- TypeTest SPT Test psi 1751 - OA 120 300 290 290 Interval - P/F P - Tubing 2500 2500 2500 2500 Notes: pretest pressures observed and found stable. st,ANNED FEB I 6 Z0/2. Wednesday, January 11, 2012 Page 1 of 1 MEMORANDUM Toy Jim Regg ~ ~ ~~ P.I. Supervisor ~ ~~~~ ~ ~ ~~ ~ FROISt: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, January L5, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) NC B-12 MILNE PT UNIT KR B-12 Src: Inspector NON-CONFIDENTIAI, Reviewed By: P.I. Suprv '~.Jf~ '~ Comm Well Name: Mll,iv>/ PT CTNIT Kx s-IZ ~ API Well Number: so-o29-2t~3s-oo-oo Inspector Name: Bob Noble Insp Num: mitRCN0801 t 1173845 Permit Number: 185-080-0 ~ Inspection Date: Ii11;2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~- _ W Well i a-i` ;Type Inj. ~TVD ' IA 7005 a ~ aao ! 1950 ' ~ I -r----- -~- ]930 I 1930 i i _ ! 1850800 ~ I SPT '; P.T. ~TypeTest i ;Test pSl i _ _ 1950 ', ~ _ _ 290 450 _ __ _ -.-.-- 4~0 ! 450 ~~ ~ P Interval 4YRTST P~F ~' Tllhing 2280 2280 ~ 2280 ~ 2280 ~ _ Notes: ~ _ . Tuesday, ,ianuary 15, 2008 Page 1 of 1 l"-L. ¡Vll v ~ ~ (,L'-'-' J '-,,~ ~ \,.~?/ Tom, We'll definitely plan to keep you informed on the results. Thanks! Jennifer From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, February 27, 2007 3:29 PM To: McLeod, Jennifer D Cc: Ohms, Danielle H; Chesher, James R SCANNED FEB 2 8 2007 Subject: Re: MPU Tracer Test Jennifer, We always appreciate notice of impending "tests". According to Ala 1 O-B, tracer fluids have been approved for use in the Kuparuk and Schrader Bluff formations at Milne. Since the tracer fluids have been approved, there really isn't a need to seek approval. However some sort of communiçation, seems appropriate to keep the Commission informed. I would disagree about no requirement to.. . report. I'd expect that any tracer results would be reported as part of the the annual report required by 20 AAC 25.432 (2). I look forward to hearing further details. Call or message with any questions. Good luck with the project. Tom Maunder, PE AOGCC McLeod, Jennifer D wrote, On 2/27/20073:18 PM: Hi Tom, We are gearing up the planning for pumping Bright Water again this summer in a couple of patterns at Milne Point. To get some information on water breakthrough timing to help size a job in one of the patterns, we are hoping to pump a tracer test in MPE-23i in the next few weeks. This tracer is a benign flourescent dye, the same as was used on the MPB-12}pilot pattern in 2003. If the timing isn't too quick, this will be one of the patterns treated this summer. Since this is not a stimulation, I don't think we have a requirement for reporting, but wanted to keep you informed as the 2007 Bright Water program progresses. Prior to pumping the Bright Water treatments, we plan to submit forms for approval. Please let me know if you have any questions. Thanks! \<6-5 -a~() Jennifer :Jv1cLeod MPU Production Engineer 564-5764 1 of 1 2/28/2007 3 :22 PM RE: Success of Bright Water e e Sub.iect: RE: Success of Bright Water From: "Ohms, Danicllc H" <OhmsDH@BP.com> Date: Tuc, 06 Dee 2005 11 :21 :20 -0900 To: Thomas Maunder <tom maundcr(â~admin.state.ak.us::> - '.' "'À'(~~:~1:("..','!:'~":~~1:;' ':". '~~I'~ :;\1 ,/II~!~:I')~i':.'~ '¡, II~! ,~~t~'" ' " " ~I, Tom, k~ t'Nè' ? 0\ (1'- \: ß- \ ~ I've worked with Steve Cheung on BrightWater (as BP and Chevron are in the consortium developing the technology) and sorry I missed the SPE lunch yesterday. I'm on the slope this week. Jennifer McLeod and I are just reviewing some of the welltest results from B-04 and B-03 which are offsets to the well we pumped BW in, B-12i. I can't say we've seen any conclusive production results so far, but have a few pieces of surveillance data that are encouraging. We are still monitoring and hopeful that oil production increases will result. We are in the process of reviewing data with the company experts so really don't have much to share at this point. Our well spacing is considerably larger than the one Steve may have talked about in the Indonesia pilot, and the MPU wells have had some periods on and off production and injection, delaying results. I'll do my best to keep you posted as we come to more conclusive results (though don't hesitate to ask again in a few months if I haven't gotten back) . Danielle -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 05, 2005 2:42 PM To: Ohms, Danielle H Subject: Success of Bright Water Hi Danielle, I attended the SPE lunch today. The speaker was from Chevron and he discussed profile modification techniques and mentioned Bright Water. How has the application of this technology gone in Milne. Thanks in advance for the reply. Tom Maunder, PE AOGCC ~CANNEt... ., KÆ, (JOD5 .1Uf- .,..~-_.-- ,! 1 of 1 12/8/20052:18 PM '. (' STATE OF ALASKA (' r"'~r/~E~" ¡ ALASKA OIL AND GAS CONSERVATION COMMISSION r'\r:t.l,.....,~\1 EfJ REPORT OF SUNDRY WELL OPERATION5JL 0 ~~ 2004 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate Di!\!askwáw,¿ÞQa:~ Con;:~. C!QtJ¡ratŒ!)n Stimulate 0 Time Extension [!J:;:~: ¡i ~ ;::r;!~ Re-enter Suspended WellD Bright Water Inj 5. Permit to Drill Number: 185-0800 Name: BP Exploration (Alaska), Inc. Development D 59.00 8. Property Designation: ADL-L047438 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: MPB-12 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit Exploratory 0 Service ŒJ 6. API Number 50-029-21338-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 7964 feet true vertical 7339.9 feet Effective Depth measured 7920 feet Plugs (measured) Junk (measured) None 7773 true vertical 7302.0 feet Casing Length Size MD TVD Burst Collapse Conductor 85 13-3/8" 48# H-40 35 - 120 35.0 - 120.0 1740 750 Production 7887 7" 26# L-80 33 - 7920 33.0 - 7302.0 7240 5410 Surface 4788 9-5/8" 36# K-55 34 - 4822 34.0 - 4659.1 3520 2020 59.0 - 59.0 59.0 59.0 Perforation depth: Measured depth: 7724 - 7757 True vertical depth: 7133.2 - 7161.55 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 31 7697 Packers & SSSV (type & measured depth): 3-1/2" BOT HB Hydraulic Packer 3-1/2" Otis HVT Packer @ 7640 @ 7575 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 -1805 450 13 0 0 -1627 0 Tubing Pressure 5449.9 5373.3 Prior to well operation: Subsequent to operation: Oil-Bbl 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service]] 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG 0 GINJD WINJŒ] WDSPLD Daily Report of Well Operations. X Prepared by Sharmaine Copeland (907) 564-4424. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Sharmaine copel~nd 304-222 Printed Name Sharmaine ~o.eel~Ø /J (7', . Title Technical Assistant Signa~~,(It/t?14A~ ,¿/~~- Phone 564-4424 Date 6130/04 ? ORIGINAL ..-I8FL Form 10-404 Revised 12/2003 Copies of Logs and Surveys run- JUl 05 1"04 ( ( MPB-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/16/04 T/I/O= 1600/12010 ATTEMPTED TO LOCK OUT TRSSSV WITH NO LUCK. PUMPED 10 BBLS 7.5% ACID DOWN TUBING AND LET SOAK TO ACIDIZE SCALE IN SSSV. RDMO FT 11/0= 2000/12010 06/17104 Start Bright Water chemical injection. FLUIDS PUMPED BBLS 10 2 7.5% Acid source water 12 TOTAL Page 1 "i WELL No. B-12' COMPLETION SKETCH MILNE POINT UNIT (I) API No.: 50-029""21338 PERMIT No.: 85-80 COMPLETED: 5/14/85 LAST WORKOVER: 9/3/91 ,...---.... . NOTFS: ,. All MEASUREMENTS ARE FROM KDB OF NABORS RIG NO. 27E KDB - Sl = 59' .., KDB -' Gl = 35' 2. MAX. ANGLE = ~ 0 3700' MD (sssv ) 3. K.O.P. I: 3000' 4. SlANT HOlE: YES 5. MIN. ANGlE = 29. 75. AT 6800' tAD 6. TREE TYPE: FMC 3 1/8- API 50001 WllH 3 1/2. 8 RD. TREETOP CONNECTION. 7. MIN. RESlRlCTlON IS CAMCO 'D' NIPPLE (2.75- 10) 8. COMPlE11ON FLUID: 8.6 PPG NoCl BRINE W/12X MeOH r'. ... M- Cl '.... ~~. PF~FORA T1oNS; 12 SPf AT 120. PHA~NG MK-1, MK-2 7724'-7757' tAD 7133' - 7163' TVD (BASED ON DIL LOG OF 5-10-85) - .~. ~ CONoca INC. ANCHORAGE DIVISION I FMC TUBING HANGER W/ 3 1/2. 'H' BPV PROFlLE 3 1/2., 9.31 L-80, Brd EUE (2.992. ID) 569' CAMCO TRDP-IA-SSA-SCSSV (2.812. ID) :11 7596' CASING R.A. MARKER 7575' OTIS .Hvr PKR 1 JT 3 1/2., 9.31, L-80. 8rd me SEAL ASSEMBLY 7619' BOT PBR 7640' BOT 'HS' HYDRAULIC PACKER (2.89. ID) 7685' CAMCO 'D' NIPPLE (2.75" ID) 7697' TUBING TAIL - 7773' TOP OF FISH ... 7920'--7., 26 LB/fT L-80 STRS (6.276" ID, 6.151. DRifT) I APPROVED BY: HDS DATE: 03/26/92 DRAFTED BY: SJN CAD FILE: WCOB12 1. Type of Request: Abandon D Alter Casing D Change Approved Program ŒI 2. Operator Name: k , "IL~ r' l''''~ r-- ~! ~\ ! r:~ (, ( ( STATE OF ALASKA ( f'( 1l:: t,l' t:J \ß' t::'J,-J9' ( 6 ALASKA Oil AND GAS CONSERVATION COMMISSION JUN 0 97 04 ~ APPLICATION FOR SUNDRY APPROVAL - ,. _°. ~ 20 AAC 25.280 AlaSK3 Oit 8~ L:':i;¡;". Lm¡¡in:;;S¡Gf1 Suspend D Repair Well D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Am,;!¡tH c¡~e PerforateD waiverD Annular DisposalD StimulateD Time ExtensionD OtherŒJ Re-enter Suspended Well 0 Bright Water Inj 5. Permit to Drill Number: 185-0800 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 59.00 KB 8. Property Designation: ADL-047438 11. Total Depth MD (ft): 7964 Casing Development D Exploratory D 6. API Number 50-029-21338-00-00 Stratigraphic D Service Œ] 9. Well Name and Number: MPB-12 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 7920 7243.0 Size MD TVD ¡Total Depth TVD (ft): 7339.9 Length Junk (md): 7773 Collapse Conductor 85 Production 7887 Surface 4788 Perforation Depth MD (ft): 7724 - 7757 Packers and SSSV Type: 3-1/2" BOT HB Hydraulic Packer 3-1/2" Otis HVT Packer 12. Attachments: Description Summary of Proposal D Detailed Operations Program ŒI 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Plugs (md): None Burst 13-3/8" 48# H-40 7" 26# L-80 9-5/8" 36# K-55 Perforation Depth TVD (ft): 7133.2 - 7161.6 top bottom top bottom 35 - 120 35.0 - 120.0 1740 750 33 - 7920 33.0 - 7302.0 7240 5410 34 - 4822 34.0 - 4659.1 3520 2020 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 " 9.3 # L-80 31 - 7697 Packers and SSSV MD (ft): 7640 7575 BOP Sketch D 13. Well Class after proposed work: Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D GasO WAG D GINJD Service Œ] June 22,2004 PluggedO AbandonedD WINJ ŒI WDSPLD Prepared by Garry Catron 564-4657. Date: Contact Danielle Ohms Printed Name Signature / ~~lIe Ohms /á-1/fÁ./~( t-:?/ú~" 6/8/04 Title Phone Petroleum Engineer 564-5759 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug In~ 0 Other: SUbseq~æ. A ApprovedDy¡ ~"V'\ Form 1 0-403 Revised 12/2003 I Sundry Number: . 3D t.f -- d-"d-~ BOP TestO Mechanciallntegrity Test D Location Clearance 0 ~o \-\ '"~~~ ~~~-\ bt:~"~ BY ORDER OF THE COMMISSION Date: ft}r ~ J\~)\~¡íl e OR\G\NAL SUBMIT IN DUPLICATE ò ( ( To: J. Bixby / C. Spence Date: June 9,2004 Well and Field Operations Team Supervisor From: Danielle Ohms (Senior Production Engineer) Nick Frazier (B Pad Engineer) Craig Graff (Nalco) Subject: BP Milne Point 812i BriqhtWaterTM Waterflood Conformance and Diversion Treatment Both BW materials are supplied in liquid, pump able, and concentrate form. Pumps have been designed and specially ordered for the application. The pumps and motors specified for this application will operate at a constant 1750-rpm. Each pump head has an adjustable plunger stroke allowing it to pump between 5 and 47.8 gallons per hour into 2900 psi. Since these are positive displacement pumps, the chemical rate will not vary below that maximum pressure. A drawdown sight glass will be used to set the target rate. A 1°k polymer solution will be achieved, by injecting 35.3 gph of EC9368A and 17.6 gph of EC9360A if the water rate is 2016 bwpd. The products are dosed into the water injection line at convenient points near sites of turbulence. The surfactant, EC9360A will be injected at the bottom of the S-riser, and the polymer will be injected into the sample point at the top of the S-riser. Turbulence between the addition points mixes in the surfactant allowing the BW emulsion to wet out. Shear after the addition of the emulsion is intended to emulsify the carrier oil, make the surfaces of the BW particles hydrophilic and disperse them individually into the injection water. The shear must be adequate to wet out the particles singly, as multiplets of particles could potentially cause near well bore injectivity loss. A slightly closed wellhead valve, a multi orifice type strainer plate, or other such constriction typically represents sufficient shear to achieve good mixing. It is likely that the chemical injection lines will be connected and removed without shutting-in the well. The injection points on MPB-12i are nipples welded onto the line with gate valves and a cap on the end of the nipple. Typical procedures on the North Slope call for maintaining a IIdouble blockll between atmosphere and the system. In this case a procedure will be specified for connecting and removing the injection lines with only the valves isolating it from the system. The connections were originally installed as sample ports and are designed to be used in that manner. ( f 1/2" NPT fitting to be used for EC9368A injection "~~-rJ:,,,,....,.~ W ell Head W' NPT fitti Ig to be used fo EC9360A injection 'w¡di 2" Well Line Well House Floor , ~ ~,¡ . ~'~ . !'II f' ~~~1 Figure 6. Bright Water injection arrangement at the B-12; Well House Note 1: If the water injection rate falls by more than 200/0 other than early in the injection phase, then stop injecting chemical displace the well bore fluid away into the formation. When the flow rate has recovered, resume chemical injection at addition rate reduced by 500/0. Note 2: In the event of a major metering pump problem, stop all chemical injection, and flush the well bore contents into the formation. It is then preferable to stop water injection until the metering pump is fixed. In the event of stoppage of the water injection stream, discontinue chemical metering immediately. A small slug of the full concentration BW materials left in the well bore should inject away, but a large slug of the mixed surfactant and particle concentrate could give injectivity problems, as the viscosity will be high relative to water. Wellhead (and if possible down hole) pressures should be monitored and recorded during injection. Attachments: Job Procedure Well bore Schematic cc: NSU, CIC Production Chemist B12i Well File MPU Wells Admin. Assist.: Mark O'Malley/ Lee Holme Brian Bixby/Dale Deyonge ACT, ENV Advisor JOB PROCEDURE f ( . 1. Hold HSE meeting. 2. Locate and set up containment for 2 IMO containers (tank truck trailers - 6000 gal. each) and pumps. With 110% containment requirements, minimum containment volume should be 13200 gal. 3. Locate the following equipment on site: - First IMO's of EC9360A and EC9368A - 2 Milton Roy C model pumps - 3 phase, 480V, 30kw generator to power pumps 4. Connect the pumping apparatus. If the connections can not be made safely with the valves in place, the well will need to be shut-in and the flow line depressured prior to connection and disconnecting the lines to the injection point. This should not be necessary. If it is, the well should be allowed to establish a stable injection rate before the treatment injection is started. The well should also be allowed to inject produced water for at least 3 days after the treatment is completed before the well is shut-in. 5. Start EC9360A injection at 17.6 gph. This is the surlactant, and injection should be started with this product before starting the EC9368A injection. If water injection rates are significantly different from 2016 bwpd, the EC9360A rate should be adjusted to be 0.5% by volume. 6. Start EC9368A injection at 35.3 gph. If water injection rates are significantly different from 2016 bwpd, the EC9368A rate should be adjusted to be 1 % by volume. 7. The total volume of each chemical to be pumped will be 15,581 gallons of EC9368A, and 7,080 gallons of EC9360A. This means that trucks will need to be changed as they empty. There will be 3 tanker loads of EC9368A and 2 loads of EC9360A. When a truck becomes empty, EC9368A should be shutdown first, followed by the EC9360A. The truck should be changed out and the lines reconnected, and the pumps restarted as per steps 5 and 6. 8. When the total volume of EC9368A has been pumped, shut down pumping operations and rig-down. 9. Ensure that water injection is maintained for at least 3 days after pumping is complete before shutting in the well. (' ~' WELL No. B-12 . COMPLETION SKETCH MILNE POINT UNIT (I) API No.: 50- 029'" 21338 PERMIT No.: 85-80 COMPLETED: 5/14/85 lAST WORK OVER: 9/3/91 I FMC TUBING HANGER W/ 3 '/28 'H' BPV PROFILE 3 1/2-, 9.3# L-80. Srd EUE (2.992- ID) ,.,,---..... , NOWS: ,. ALL MEASUREMENTS ARE FROM KDB Of NABORS RIG NO. 27E KDB - Sl = 59' KDB -' Gl = 35' (sssv ) 2. MAX. ANGLE = ~ 0 3700' MD 3. K.O.P.. 3000' 4. SLANT HOlE: YES 5. MIN. ANGlE == 29.75' AT 6800' t.tD 6. TREE TYPE: FMC 3 1/88 API 50001 WllH 3 1/28 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO '0' NIPPLE (2.75" ID) 8. COMPLETION flUID: 8.6 PPG NoCl BRINE W /12% MeOH ,r----, ...~ Mw tT .... A ~~. PF'~FQRA TlOO$: 12 SPF AT 120' PHASING MK-1, MK-2 7724'-7757 MD 7133'-7163' TVD (BASED ON DIL LOG OF 5-10-85) - ,;---- , .' ...- CO NO CO INC. ANCHORAGE DIVISION -.--'- 569' CAMCO TRDP-IA-SSA-SCSSV (2.8128 10) .. ",," 7596' CASING R.A. MARKER 7575' OTIS 8HYr PKR 1 JT 3 1/28. 9.31, l-80, Brd mG SEAL ASSEMBLY 7619' BOT PBR 7640' BOT 'HB' HYDRAULIC PACKER (2.89" ID) 7685' CAMCO 'D' NIPPlE (2.75- ID) 7697' TUBING TAIL - 7773' TOP OF FISH ~ 7920'--78, 26 LS/FT L-80 STRS (6.276- ID, 6.1518 DRIFT) I APPROVED BY: HOS DATE: 03/26/92 DRAF'TED BY: SJN CAD FlLE: WCOB12 RE: MPU B-12i Bright Water Injection ,¡ \ ( Subjeèt: RE: MPU B-12i Bright Water Injection From: "Ohms, Danielle H" <OhmsDH@BP.com> Date: Thu, 10 Jun 2004 16:07:49 -0800 To: Thomas Maunder <tom_maunder@admin.state.akus> \ ~ 5 --O<G-Ù Tom, Initial waterflood breakthrough at B-03 was -5 months when injecting 3000 bwpd (jumping from 0 to 50% wc in 1987, and rapidly increasing from there when returned to production in 1989, reaching 94% wc by 1991). A pulse test between the wells confirmed strong communication, layered behavior, and no fault or fracture noted. The relatively large kh of 1400 md-ft indicated that the thief zone dominates the communication. Past attempts to try a cement squeeze and setting a plug to isolate the thief layer at Producer B-03 have not been successful due to lack of a competent, extensive shale to separate the thief layer in this area. Danielle -----Original Message----- From: Thomas Maunder [mailto:tom ma.under@admin.state.ak.us] S en t: Thursda y, June l'O-;.."'."'2"6Ù"4."'''..2.-..;..O.6''''''''PM..''..''-..'...'''''''.''..,....-...............,-...---.....-................--......-.-........................h.-...'..... To: Ohms, Danielle H Subject: Re: MPU B-12i Bright Water Injection Danielle, In your note you B-03. What is a Thanks, Tom mention about the fast cycle time from MPU-B12i to fast cycle time?? Did you use tracers to determine this?? Thomas Maunder wrote: Danielle, Thanks. The word "paper" came through garbled. Tom Ohms, Danielle H wrote: Tom, Here's some follow-up information on the MPU Bright Water Injection for which you recently received a Sundry Application: Bright Water is a novel "designer" polymer about to be tested at MPU for deep waterflood conformance improvement. The objective is to reduce water cycling through the high permeability connection between MPU Injector B-12i and Producer B-03 (4000' away). The fast water transit time through high perm matrix rock prevents efficient waterflood sweep of reserves in the layers above and below. The setting up of the Bright Water polymer is based on a thermal/time trigger, and in the case of B-12i is expected to set up in the thief layer at the thermal front approximately 2000' from the injector. It has been trialed with Chevron in Indonesia with success and documented in SPE paper # 84987. Another SPE paper, #89391, provides more in depth detail on how this "designer" polymer works. «SPE 89391 Tulsa final prot.ZIP» «SPE International Symposium_84897_18JuI03.doc» If you want more information please give me a call. Danielle Ohms 564-5759 1~2 6/14/2004 7:53 AM MPU B-12i Bright Water Injection ( Subject: MPU B-12i Bright Water Injection From:' "Ohms, Danielle H" <OhmsDH@BP.com> 'Date: Thu, 10 Jun 2004 13:35:35 -0800 To: tom_maunder@admin.state.ak.us CC: "Catron, Garry R (S1S)" <CatronGR@BP.com>, "Townsend, Monte A" <TownseMA@BP.com> \S's- ~O?>Ù Tom, Here's some follow-up information on the MPU Bright Water Injection for which you recently received a Sundry Application: Bright Water is a novel IIdesignerll polymer about to be tested at MPU for deep waterflood conformance improvement. The objective is to reduce water cycling through the high permeability connection between MPU Injector B-12i and Producer B-03 (4000' away). The fast water transit time through high perm matrix rock prevents efficient waterflood sweep of reserves in the layers above and below. The setting up of the Bright Water polymer is based on a thermal/time trigger, and in the case of B-12i is expected to set up in the thief layer at the thermal front approximately 2000' from the injector. It has been trialed with Chevron in Indonesia with success and documented in SPE paper # 84987. Another SPE paper, #89391, provides more in depth detail on how this "designer" polymer works. «SPE 89391 Tulsa final prot.ZIP» «SPE International Symposium_84897_18JuI03.doc» If you want more information please give me a call. Danielle Ohms 564-5759 89391 Tulsa final Content-Description: SPE 89391 Tulsa final prot.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 ......... , SPE International : Content-Description: Symposium - 84897 _18Ju103 .doc ¡SPE International Symposium_84897_18JuI03.doc i Content-Type: application/msword Content-Encoding: base64 ..,....., .............". .......,",........... "."'... """... ."".... , .. .... .. ., .."......,,,....................... 1 of 1 6/10/2004 1:56PM \ \ cc.CX S<è \'( \ ~Hì ~~\~O \t)'MJ I I SPE 89391 Development of a novel waterflood conformance control system H. Frampton SPE & J. C. Morgan SPE, BP Exploration and Production Co. Ltd.; S. K. Cheung SPE & L. Munson SPE, ChevronTexaco Energy Research and Technology Company; K. T. Chang SPE & D. Williams SPE, Nalco Company Copyright 2004, Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2004 SPElOOE Fourteenth Symposium on Improved Oil Recovery held in Tulsa, Oklahoma, U.S.A., 17-21 April 2004. This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper, as presented, have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at SPE meetings are subject to publication review by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to a proposal of not more than 300 words; illustrations may not be copied. The proposal must contain conspicuous aCknowledgment of where and by whom the paper was presented. Write Librarian, SPE, P.O. Box 833836, Richardson, TX 75083-3836, U.S.A., fax 01-972-952-9435. Abstract An Industry Consortium (BP, ChevronTexaco and Nalco Company) conducted a joint research project known as Bright Water. The goal of this project was to develop a novel, time- delayed, highly expandable particulate material that would improve the sweep efficiency of a water flood. In November 2001, the first of these water flood profile modification treatments was pumped in the Minas field, as reported in SPE 84897 (1). An overview of the development of the particulate system is given in the present paper. The polymeric "kernel" particles are capable of "popping" under the influence of temperature and time. The expanded particle can then provide resistance to fluid flow in porous media. Various properties of the kernel dispersions are summarized. Laboratory tests representative of the deployment of the product are presented to illustrate the injection, propagation and popping of the particles. Screening criteria for application of the product are reviewed and related to product selection for the field trial. Introduction Over the last 40 years there has been a concerted effort to improve the recovery of oil by mobility control using polymers and polymer derived gels (2). Much ofthe work has focussed on near wellbore gel treatments using polymers and gels but there has also been considerable work on Polymer flooding and hybrid derivatives of this (3-7). All flooding polymers alter the water mobility in the reservoir predominantly by changing the aqueous viscosity. The ratio of the apparent viscosity of the treatment (as calculated from pressure measurement during treatment injection) to the viscosity of water in the same conditions is known as the Resistance Factor (or RF). Some polymer can also adsorb on the rock pore walls to leave a lasting change through altering the hydraulic radius of the pores and thus the permeability of the rock. The ratio of the effective permeability of the rock pores to water flow before treatment to the effective permeability after flushing the treatment out is known as the Residual Resistance Factor (or RRF). The polymer flooding process has some strengths, but also a number of weaknesses. In particular the polymers are sensitive to salinity, temperature, shear and biological degradation to differing degrees. The better perfonning polymers tend to use more expensive monomers or production processes. There are also limitations related to the reservoir flooding process. High viscosity of the polymer flooding solution limits the injection rate at any given injection pressure. The maximum usable viscosity is typically limited to between three and ten times that of the injection water (RF maximum of 10). There are added risks of the injector fracturing and of polymer shear degradation. Unfortunately, the effectiveness of the process is reduced at low viscosity, and overall this severely restricts the range of viable applications. In the field projects where polymer flooding has been used with technical success, the cost of the accelerated oil is relatively high. In 1996 it was estimated as $8 to 10 per barrel (8) but more recently a review of the field wide commercial polymer flood in the Daqing oilfield (5) found that in this mature field, with easily accessible fresh water, the fully accounted cost was $9.34 per barrel compared with $9.42 for continued water flood production. It is apparent that a less restricted, more cost effective method for improving sweep efficiency in oil reservoirs would be desirable. This could be achieved by injecting a low viscosity material, which subsequently triggered to form a highly viscous or blocking phase. Concentrating on the permeability reduction element of the waterflood modification should result in a system that uses most of the injected materials to produce a lasting effect. It would also ensure that injected material was never subsequently produced with the water from the field. Field trials and commercial applications of gel systems intended to achieve this have been reported (9,10) but it is unclear how far the gelant penetrates into the reservoir (11). The water injected into oil reservoirs is often cooler than the reservoir rock and this leads to the formation of a temperature front, usually somewhere between the injection and production wells. In one reported development on th.ese lines, 2 l I~, a polymer and a crosslinker were injected which would not react significantly until they reached the temperature front, at which point they formed a water-blocking gel (10). However, a trial with this Deep Diverting Gel system suggested that conventional gel mixtures were not likely to achieve waterflood profile control at a sufficient depth within the reservoir. Propagation of low levels ofunreacted crosslinker was seen as being particularly difficult to control. The present paper presents results on the development and laboratory testing of a system based on the expansion of thermally sensitive particles which can be used to cause a blocking effect at the temperature transition in an oil reservoir (12). The material is a highly crosslinked, sulfonate-containing polyacrylamide microparticle in which the conformation is constrained by both labile and stable internal crosslinks. When subject to elevated temperature, the rate of decrosslinking of the labile crosslinker accelerates. This reduces the crosslink density of the particle and allows the particle to expand by absorbing the surrounding water. The particles are applied in constrained state - called kernel particles for convenience. After heating these are able to swell to adopt a much- expanded configuration, called popcorn here. The reduction in reversible crosslink density is also time dependent and can be affected by the pH of the fluid. Different labile crosslinkers have different rates of bond cleavage at different temperatures. The temperature required and the mechanism of bond dissociation depends on the chemical structure of the crosslinker. For example, when the labile crosslinker is a diacrylate ester, hydrolysis of the ester linkage becomes the most likely mechanism of de-crosslinking. Proper selection of crosslinker can give particles with different activation temperature. The presence of stable cross linker gives conformational integrity to particles, especially after popping. The kernel microparticles are prepared using an inverse emulsion polymerization process to assure a pre-selected particle size range. Depending on the synthetic method, the original particle diameter of the polymeric microparticle can be made ranging from about 0.1 to about 3 microns. In general, the distribution has a standard deviation about 30 percent of the value of the median. Representative preparations of cross-linked polymeric microparticles using emulsion polymerization process are described in U.S. Patent Nos. 4956400, 4968435, 5171808, 5465792 and 5735439. Alternatively, the polymeric microparticles cross linked with labile cross links are prepared by internally cross linking polymer particles which contain polymers with pendant carboxylic acid and hydroxyl groups. The cross linking is achieved through the ester formation between the carboxylic acid and hydroxyl groups. The esterification can be accomplished by azeotropic distillation (US Pat. 4599379) or thin film evaporation technique (US Pat. 5589525) for water removal. For example, a polymer microparticle prepared from inverse emulsion polymerization process using acrylic acid, 2- hydroxyethylacrylate, acrylamide and 2-acrylamido-2- { SPE 89391 methylpropanesulfonate sodium as monomer can be converted into cross linked polymer particles by the dehydration processes described above. The microparticles prepared in inverse emulsion form can be dispersed into aqueous media with agitation and the aid of inverting surfactants. Due to their highly crosslinked nature, the size of the kernel microparticles changes very little in solutions of different salinity. Consequently, the rheological properties of the carrier fluid are not affected by the salinity change encountered in a subterranean formation. Accordingly, no special carrier fluid is needed for treatment. Only after the particles encounter conditions sufficient to reduce the crosslink density, is the fluid rheology changed to achieve the desired effect, which is a viscosity and/or a Residual Resistance factor capable of diverting water out of a thief zone. With a near wellbore treatment, such as that used to block thief zones bounded by coherent shales or other barriers, very high Residual Resistance Factors, greater than several hundred, are usually needed to achieve a block sufficient to divert water into less permeable zones. By contrast, a blocking material placed hundreds offeet from the we lIb ore requires a much lower RRF to achieve useful diversion. A treatment designed to work much deeper than normal in the reservoir may be designed with much larger volumes. Bright Water is such a treatment and is intended to produce a relatively low RRF over a fairly large volume at a significant radius. Simple simulations carried out in the early stages of the investigation showed that if a treatment volume of 2 to 5% of the movable pore volume in the streak was pumped to half- way down the streak (reaching a typical radius of several hundred feet) and triggered to reduce permeability, then optimal incremental recovery occurred with RF's that ranged from 30 to 100. Preparation of kernel particle suspensions The kernels particles were supplied as a 30% dispersion in a light mineral oil. This was dispersed into the test brine with high shear intended to simulate the field makeup of the products. Dispersing such products is one instance of technology easier achieved in the field than in the laboratory because higher shear environments are routinely available. The required amount of synthetic brine was placed in a beaker and stirrer with a turbine (Ultraturrax TM) mixer at low speed to form a vortex. The required level of dispersing surfactant was added to the side of the vortex and allowed to mix in for 30 seconds then the mixer was turned up to full speed and the required amount of particle emulsion was added in a similar manner. High shear mixing was continued for 10 seconds then the speed was turned to low for 30 minutes. The mixture was subsequently conditioned for 5 minutes in an ultrasonic bath (Decon Ultrasonics Limited, FS400 Ultrasonic or equivalent) then was ready for use. The aim ofthis procedure was to ensure that the particles were individually dispersed, SPE 89391 ( rather than as aggregates, in the brine. Slim tube tests The popping action of the particles was designed to take place after a significant time, allowing them to propagate hundreds of feet from the injection well. Accordingly, a porous medium that could allow for propagation at a low rate over a significant time was required. Slim tube sand packs were constructed to permit this. An additional benefit is that capillary end effects are minimised because of the greater than usual length of the test pieces. All of the tests were done using a synthetic, brackish water formulation relevant to ChevronTexaco fields in Indonesia and with the analysis shown in Table 1. Table.1 Analysis of the synthetic test water Ion Concentration (mg/litre) 1497.2 40 6.1 11.6 1350.9 46 1645.9 4571 Na+ K+ Mg2+ Ca 2+ cr S042- HC03' TDS Characterization of the porous media and particles The porous media used in the tests were characterized by mercury porosimetry to determine the pore throat size distributions. Core fragments were used or small packs specially prepared to fit into the test container of the porosimeter. A %" length of %" internal diameter 313 stainless steel tube was prepared by similar means to the slim tube sand packs. A 45-micron stainless steel mesh was fixed to one end of the tube using epoxy resin adhesive and then allowed to dry thoroughly into place. A compression fitting union was attached to the open end of the pack and used to fill it with sand, which was tapped to settle it into place, then wet with deionised water and tapped again to remove any bubbles. The procedure was repeated until the small pack was full of sand then the union was removed. The sand surface was trimmed and flattened against the top of the tubing then, after cleaning the tube end, a second disc of mesh was glued onto the open end of the pack. After the adhesive set, the pack was dried and tested using a Micromeritics Autopore 9420 Instrument. Particle size distributions for the Bright Water kernel particles were measured using a Malvern Instruments Mastersizer E. Figure 1 shows a comparison of the size distributions of the kernel diameters with the pore throats of some relevant porous media used in the proving tests. The particle size distribution for the kernel particles overlaps the low diameter tail of the pore throat size distribution. This might be construed to represent a problem for injection and propagation, but in practice, as shown later, it is not. Mercury porosimetry determines the volume of mercury taken in by the sample of ~: 3 porous medium at each pressure applied and relates this to the volume represented by pores of diameter equivalent to the pressure applied. In systems with tortuous pores and varying pore diameter, including ink-bottle pores, the teclmique tends to overestimate the frequency of small pores by including with them the volume of any larger radius pores situated between them and the next smallest pore throat (13). In other words there are usually many fewer small pore throats than mercury porosimetry would suggest. The peak in the pore throat size distribution is usually reliable. The particle sizes are similar to the Root Mean Square end-to- end distances (molecular sizes) for synthetic mobility control polymers in 1.0 Molar (8.5 percent weight per volume) Sodium Nitrate as estimated by Lynch and MacWilliams (14). Figure 1. A comparison of the pore throat diameters of porous test media with the kernel particle sizes 80 70 ' . Kernel sample 1 ... Kernel sample 2 - North Sea core ...-- Minas core 60- Ii " II II II I I , I I I I r ~ " l , J ! \ ........."'~... ~t \ --~ ~--~... ~."l I \ ---.r--' ,.. .""-;;-- - -~ -N...."'''''' - \ , ..... -_.., \, .0,1 ,..nUlla--" Diameter (M' 1 _I_baa Icrons) 10 100 >050 - CJ C Q ::::140 C' e LL 30 -- F-sand 20 10 ,--- 0 0,001 0,01 Particle injectivity There are many published instances of formation damage being caused by particles (15). Filtration theory suggests that this can happen even if the particles are smaller than the pore throat size of the medium under test (16). Particles will typically pass through filters or porous media if the minimum pore throat diameter is at least about 7 times larger than the particle diameter (16). The exact ratio depends on other properties alluded to earlier and in particular the concentration of the particles present. The kernel particles, with properties optimised to propagate well are approximately centred on 0.5 microns and are 15 to 30 times smaller than the pore throat diameters of the media used in testing. It was necessary to demonstrate that the Bright Water particles could be injected into representative porous media without causing blinding or "near wellbore" damage. Kernel particle swelling tests Samples of the Bright Water kernel particles were dispersed in waters of various compositions at a concentration of 5000 ppm and the viscosities obtained were measured using a Brookfield L VT viscometer with UL adapter at 6 rpm (7.34 S.I). Variations in viscosity were taken to represent swelling of the kernel particles by absorption of the water. Filtration tests Filtration tests were used to study the optimum level of inverting surfactant required by the kernel dispersion. This 4 was to ensurè that the injectivity tests represented the prop6rties of the individual particles. Solutions were prepared at various compositions then tested using the procedure set out for EOR polymers in API RP63 (17). Figure 2. Filtration tests to determine the optimum level of surfactant for Bright Water mixing Filtering Time for EC9368A Through 1 urn Nucleopore at 30psi Pressure 2500 ,-.. 1500 ~ Š ¡::; 1000,-- ~,/,/~ ..-.- ):: /,-.," -,-:¿' - " /7-~y ---- 1:;.".., ,,'./., /, ,.,../ -- /ý-¿- / ø-~~ "~'-_.._--"'"t 500 ,----,-- 0, 0 so 100 150 200 250 300 Volume (ml) 350 400 450 500 -- Surfactant Cone - 1500ppm Polymer Conc- 1500ppm ....... Surfactant Cone - 2500ppm Polymer Cone - 1500ppm , Surfactant Cone - 1500ppm Polymer Conc- 4500ppm .., Surfactant Cone - 1500ppm Polymer Cone - 1500ppm .-'.... Surfactant Cone - 1000ppm Polymer Cone - 1500ppm ....... Surfactant Cone - 500ppm Polymer Cone - 1500ppm ,.,.,.. Surfactant Cone - 200ppm Polymer Cone - 1500ppm Slim tube injectivity test A five-foot long, 1;4 inch internal diameter slim tube sand pack of permeability 791 mD at 65°C was used for injectivity tests. A 1500 ppm active dispersion of High Activation Temperature (HAT) Bright Water particles (sample 126-1 with median diameter 0.26 microns) was prepared using 1500 ppm active of dispersing surfactant. A total of 119.5 Pore volumes of "solution" were injected at different rates and the pressure across the tube was measured. The low pressures measured were near the bottom limit of the pressure transducers used and were consequently rather noisy. The data were corrected for baseline drift, which is necessary at such low pressures, and then the average pressure drop for each section of the experiment was calculated and converted to a Resistance Factor. There appeared to be a correlation between the injection rate and the Resistance Factor on injection as shown in Table 2 for the High Activation Temperature sample 126-1. Table 2. Resistance factor due to injection of Bright Water High Activation temperature kernel particles into a 791 mD pack at varying Darcy velocities. Injection rate Darcy PV Temperature dP av (mls/min) velocity injected (OC) (Bar) (ft/day) 1 382.98 0.1 38.30 0.1 38.30 0.1 38.30 0.1 38.30 0.08 30.64 0.06 22.98 0.04 15.32 0.02 7.66 0.01 3.83 1 CPI water 2 CPI water 3 CPI water 4 CPI water 5 126-1 6 126-1 7 126-1 8 126-1 9 126-1 10 126-1 4.9 6.8 0.1 Heatup 23.2 29.7 30.6 23.4 24.4 9.0 2.5 Estimated average RF 65 1.414 65 0.1625 N/A 65 0.03607 65 0.13231 65 0.08757 65 N/A N/A 65 0.10577 65 0.04302 65 0.1403 \ SPE 89391 Particle propagation Particle size is not the only relevant variable in particle propagation. The particle interactions with the rock and the carrier fluid are also pertinent. Tests were run to examine the propagation of the Bright Water particles in relatively penneable sand packs representative of high penneability thief zones in the Minas field. Figure 3. Resistance factor versus Pore volume injected for a 40 foot, 3.1 Darcy Sand pack test for propagation of Bright Water kernel particles at 33 ftlday Darcy velocity. 2.5 2- ~ t. .. . ~ '* : . . . "'-:. . r . . ..o;¡, f . . ~ . - 1.5 - u.. a: 0.5 0 12 13 14 15 16 17 18 19 PV Figure 3 shows that RF does not build up significantly in a linear 3.1 Darcy sand pack when approximately 4 Pore volumes of the Bright Water kernels are propagated through it (following 13.5PV of water injection with RF at 1.0). The kernels were mixed into synthetic water at a concentration of 4467 ppm active. Figure 4 shows the results of the polymer injection section of a similar experiment constructed in a pseudo radial construction where each tube moving out from the inlet had a higher internal diameter. The system was flooded with Carbon dioxide then water to eliminate free air, then flooded with Forties Reservoir crude oil, and finally with water again to reach residual oil saturation. The details of the lengths, internal diameters and permeabilities of the sections are given in Table 3. The aim of this experiment was to simulate the decrease in Darcy Velocity and the effect of dispersion encountered in radial flow away from an injection well bore. The temperature of the test was initially ramped up in two early steps to 0 0 0 0 3.67 2.43 Table 3. The construction and permeabilities of the 66-foot sand pack particle propagation test. Pack section ID (inch) k (D) 0 - 5ft 0.25 3.077 5- 16ft 0.38 1.177 16 - 28ft 0.50 2.373 28 - 50ft 0.75 1.504 50 - 66ft 1.00 0.426 1.86 1.52 9.9 simulate heating in the thief zone but was then held mainly at SPE 89391 95°C. The p'ore volume ofthe pack was 709.1 mls and the injecäon rate was 0.015 mls per minute so injection of one pore volume of fluid took 32.8 days. 0.1 Pore volumes of a 4467ppm active dispersion of Bright Water particles in synthetic field water at 23°C was injected first. At 0.2192 PV the temperature of the pack was raised to 65°C, then at 0.51 PV it was raised to 95°C. The sand pack rig was designed to measure the large pressure drops associated with such long tubes and with popped particles, so the noise in the low pressure measurements associated with particle propagation made calculated Resistance Factors very noisy also. The ease with which the kernel particles passed through the first 50 feet of the pack can be seen more clearly in the pressure difference plot. It is also apparent that there is a rise in pressure drop (i.e. Resistance Factor) across the last section of the pack at about 100 days, which is taken to be the onset of popping for this Medium/High activation temperature, experimental Bright Water sample. The RRF's observed during propagation averaged about 2 to 6 with a rise to about lOin the last section in the early stage of popping. Figure 4. Pressure drop versus time for a 66 foot, Pseudo Radial, Sand pack test for propagation of Bright Water kernel particles. J~-!-.:C~~-'-;~-:~:._-_.. H ': -r:1 .~"'\'. ,,:<;;:~~ ~:,i~}':. , The difficulties in discriminating between emulsified oil (with high refractive index increment) and Bright Water particles (with virtually none) in the pack effluent were not solved, so no effluent particle characterisation was possible in support of the propagation experiments. Particle "popping". Decomposition of the reversible crosslinker in the kernel particle leads to release of the constraints on the polymer molecule( s) in the particle allowing absorption of water and re-equilibration to give a larger particle size. The level of the reversible crosslinker and the temperature encountered affect the time required to reach full expansion of the kernels. The salinity of the water controls the popped size of the particles. The popped and unpopped sizes of the particles were studied by Scanning Electron Microscopy. Activation times were detennined using bottle and sand pack tests. ( 5 Scanning electron micrography Samples of kernel particles were dried down as a film onto scanning electron microscope grids under vacuum. The same kernel samples were also popped by boiling in deionised water until the viscosity increase levelled out. Further films were cast on grids and dried down, then compared with the originals to obtain a semi-quantitative evaluation of the effect of popping on the particles. Figure 5 shows the kernel particles compared with a I-micron scale bar. Even with the particles aggregated into a film, the sub - micron nature of the kernel particles is easily seen. Figure 5. Scanning electron micrograph of a film cast from kernel particles Figure 6 shows a similar picture after popping with a 5-micron scale bar. The base particles expanded to 2 to 4 microns dried down size and interactions are observable over a scale of 15 to 20 microns or more. L~ ~1 ' '!'~ T I I ~' Wojtnowitz et al (18) suggested that at high particle concentrations there was the possibility of a logjam of particles blocking pore throats. 6 Soo -and Radke (19) looked at the straining and capture mechanisms of solid and liquid dispersions in sand pack experiments. Solid polystyrene latex particles were compared with emulsion particles of matched particle size (2.2 microns) and zeta potential. When the authors observed the outlet particles by microscope they found clusters of latex particles that were not present in the inlet solution. Based on previous hypotheses they suggested that, because of the greater Hamaker constant of the latex particles they could form dendrites in the porous medium, which subsequently broke to form clusters of particles. These could join with other dendrites to block pore throats and some could be produced. Vitthal and Sharma (20) suggested that this can occur gradually rather than suddenly and that it does not require a high concentration of particles. It is speculated that the fully popped Bright Water blocking activity has components which include particle/wall, Particle/Particle interactions and simple bridging. Bottle tests As the kernel particles expand, the volume occupied by them increases. Consequently, the volume fraction of the continuous phase decreases. This decrease in free volume is reflected in an increase in the viscosity of the dispersion. Activation of the polymeric microparticles by heat can be illustrated in a bottle test. To carry out a bottle test, a dispersion containing 5000 ppm of the kernel particles was prepared in synthetic brine, which contained 2500 ppm surfactant to aid the dispersing of particles. Dispersing of particles was accomplished by vigorous stirring or by using a homogenizer. 1000 ppm sodium thiosulfate was added to the mixture as an oxygen scavenger. The dispersion was then placed in sealed bottles. Generally, a group of 10 to 20 bottles per condition were needed to monitor the viscosity change. The bottles were placed in a constant temperature oven for the "solutions" to age then, at a predetermined time, a bottle was removed from the oven and cooled to 7 5°P. Table 4 shows the viscosities (cP) of 0.5% active weight per volume aqueous dispersions of the latex particles aged at various temperatures in the synthetic brine (4570 ppm TDS) described in Table 1. The viscosity was measured at 75 °p using Brookfield LV No.1 spindle at 60 rpm (shear rate 13.2 sec -1). The data show, for particles of ultra high activation temperature (UHAT), no swelling was observed after 30 days at 140 °p and 175 °p. The particles began to swell after they had been heated at 210 °p for more than 10 days. Por particles of high activation temperature (HAT), no swelling was observed after 30 days at 140 °P and swelling began after at least 10 days at 175 °p or at least 2 days at 210oP. Por particles of medium activation temperature (MAT), swelling was observed quickly at 158°P. The bottle test gave a good indication of particles expansion under given conditions. The viscosity of the mixture is shown to increase with time and temperature. By themselves, however, the bottle tests do not accurately predict when an effective plug will develop, or what Resistance Pactor (or It SPE 89391 RRF) may ultimately be achieved. Unlike the bottle tests, abundant water is available in the reservoir, potentially adding to dilution and in some cases continued particle expansion. When these particles propagate in a matrix rock pore system particle/pore wall interactions also contribute. Table 4. Viscosity of a 5000 ppm Bright Water dispersion after aging at various temperatures UHAT HAT MAT Time 140 175 210 140 175 210 158 175 197 (days) of of of of of of of of of 0 3.3 3.3 3.3 3.1 3.1 3.1 3.3 3.3 3.3 2 5 9 30.4 4 17.4 28 37.4 5 4.1 5 6 13 8 27.2 48.6 74 10 3.5 4.2 7 4.2 8.9 33 94.4 14 122.5 15 14 46 16 33.8 52 128.9 20 3.2 4.8 27 5.6 20.4 49 41.7 67.9 22 143.8 24 44.5 75.5 25 30 3.6 5.7 36 5.4 40.4 55 40 4.1 7.2 6.8 37.8 48 45 57 Figure 7. Viscosity versus time for a sample of "Medium" activation temperature Bright Water particles. 160 -'-"'-'--' ' 140 .Å. Å 120 .. 100 - . 158 of D:' Å .!:!.. 80- iØ 175 of 0 WI I/) Å .Å. 197 OF :;: u¡ 60 - !III m 40 . . Å .Å.1iI1 . . 20 --.---------- 0 H___.__-,- I 0 10 20 30 40 50 Days SPE 89391 Figur~ 8. Viscosity versus time for a sample of "High" activation temperature Bright Water particles. s:- 60 ~ .. ~ 50---------~---_._-----"-------}.--- ------,._-- - Å 0 .. U III :> 40 - 8' ~ III ~ Å :~~:I :E 30 - III ¡¡: .101: 0 Å 210 of e 20 - . to ':' .. ~ 10 - .. III III . . N . . C"Ï rl . .... 0 - 0 10 20 30 40 50 Days Figure 9. Viscosity versus time for a sample of "Ultra High" activation temperature Bright Water particles. 60 .. ~ .!:!. ~ 50 - ------- ïii 0 u II) :; 40- ~ ~ 30 ~ 0 0 ~ 20 Å + 140 of !IS 175 of .. 210 of .. ... u 3: 10 - N ~ II" . 0 -,----.'------..' 0 Å .. , m IIiII , . . ~--_...- 20 30 40 50 Days 10 Slim tube sand pack tests A 30-foot long slim tube sand pack was constructed in three ten- foot sections using "F -sand". The pack was saturated with brine then raised to 203°F (95°C) and allowed to reach steady state to brine flow. The permeabilities of the three sections were calculated as 719, 814 and 620 roD respectively. The pack was then treated with 1500 ppm active of Very Low Activation Temperature kernel particles with 1500 ppm of the associated surfactant. This sample was used to achieve a very short popping time and allow a test under flowing conditions in this tube of limited pore volume. The pressure readings were monitored with time and converted to RF or RRF readings with the results shown in Figure 10. At the pressure drop of 250 psi applied over the Bright Water slug in this experiment, the popped material moved through the sand pack from section to section as shown by the progression of peaks. In a second slim tube test 0.49 pore volumes of kernels at a concentration of 2250 ppm active particles with 1500 ppm of surfactant, was injected at a rate of 0.01 mls/minute (3.83 feet per day) at 185°F into a 40 feet long, 3 Darcy slim tube sand pack at residual oil saturation, with a pore volume of 150.2 cubic centimetres. The characteristics of the sections of the pack are shown in Table 5. ( 7 Figure 10. Resistance Factor versus experimental time for Bright Water showing the peaks moving through the pack. 1-- - ------------------------~~~:-Ph 68-3 In ~-I~C:-;:;~-;-;~~~~~-----------~-~l \ I ...+-.-- 0-10ft 1 -8-- 1 0-20ft I -----~Q-~~!tJ 140.00 .. 120.00 -- 100.00 - ~ 80.00- 35.00 40.00 45.00 50.00 Cumulative days Table 5. Permeabilities of the sections of the 3 Darcy test pack. Section feet 0-1 Oft 10-20ft 20-30ft 30-40ft total pack Permeability Darcys 2.5305 3.1789 2.9817 3.3467 2.9763 The reagent injection took 5.69 days then the Bright Water was displaced with 0.287 pore volumes of water to move it into the second and third 10- foot sections of the pack, when it was shut in for one day. At the end of this time a small volume of water was injected until the measured pressures levelled off. The process was repeated at various time intervals to obtain a measure of the variation of RRF due to the polymer with time as shown in Figure 11. The total chase water injected during the shut-in-and-restart testing was 0.17 PV so all of the particles remained within the pack during the testing and the back of the slug did not leave the second section. All of the response was shown in the last 10 feet of the pack. The RRF achieved in each case was plotted against time as shown in Figure 12 below. This showed a popping time of approximately 12 days and an equilibrium RRF of about 200 from a 20 foot slug at this (relatively high) concentration of the reagent. Figure 13 shows the build up of RRF with a lower concentration of the Bright Water reagent. Figure 14 illustrates the effect of the reagent in a 124 roD Clashach core. Screening criteria for Bright Water use. Various aspects of field screening for Bright water applicability were referred to in SPE 84897 (1) as the basis for selection of Bright Water for the Minas field trial. Current understanding is that a relatively low oil recovery combined ~' 8 Figure 11. The RRF response of a 3.4 D sand pack versus time with shut in between test periods. ! 250.00 - -'llnje~tlng Oïï-[~=;~~:;;~~"::'~'::' :.~!.~~:~ "'..'".'-I~j~~:ln~'- -,'.'.'.'~"""'-"f~-~~~~~~~II I at 0.5 water at ml/min water at j I 200_00 ,-- ml/min 0.01 ml/min -,..."/ B--'.'- 0.01 ml/min -- -- 0- . . - . 1 0-20ft I ~ :0500.::~~. ~~::: - /~32s~:~_-~t~ :.~:~: . II Á.}2C 0 0 0 0.00 0.00 10.00 20.00 30.00 40.00 50.00 60.00 70.00 Cumulative days Figure 12. The change in RRF with time of test for 2250 ppm Bright Water in a kabs 3.4 Darcy silica sand at 185°F 250 - ,...,...-............."..,....,....".....,...,..............,....,..... .."..,...,.... ..,......"............................., ,.."..,............"..,..,..,....., """"1 I I ----------------------L------",___I ..................,....".............",.. 200 150 " u. 0:: 0:: 100 ' 50 0 0 r"---'---'-'-"---'-'--"'--"---"---"'--'-"'-"-'-¡ 10 20 30 Elapsed time (days) 40 50 Figure.13. RF versus ageing time at 158°F for a 4500 ppm active kernel suspension in a slim tube silica sand pack of Ksor 584mD. 60 -'" 50 - ... .s 40 u J! () ::1 30 - J!! C/ .~ 20 0:: 10 - 0 . 10 15 Ageing time (Days) 20 25 with high water cut in a pattern that has had a significant pore volume of water injected is a good basis for concluding that a sweep problem exists. If the permeability contrast vertically or are ally is 1 to 5 or greater then Bright Water is taken to be suitable and further studies are justified. SPE 89391 Figure 14. RF versus ageing time for a 4500 ppm active kernel suspension in a 3 foot Clashach sandstone core of Ksor 124mD at 158°F. 16 - 14 12 - t- o ti 10 If ell ::! 8 J!I C/ 'ëij 6 0:: 4- 2 0 ---- 0 -'--"--i'-~-'-'- 70 80 50 60 10 20 30 40 Time (Days) The laboratory data obtained in support of the trial allowed several product and process screening and planning decisions to be made. 60 30 a. The product for the field trial was selected on the basis of the anticipated popping time derived from the field water breakthrough time measurements. Various product compositions were tested and the version of the product that was expected to propagate roughly half way to the producer before popping at the temperatures expected (which were initially believed to be injection at 70°C and reservoir temperature 85°C) in the reservoir was chosen. This was the medium activation temperature sample referred to in the results presented. The planned volume of injectant was one third of the calculated volume of the streak, based on the injection rate at the target well and the understanding of water breakthrough time when the laboratory evaluation was done. The concentration of the Bright Water kernel particles was selected to give a Residual Resistance Factor of 30 to 100 in the streak after popping. This was determined to be suitable from simulation studies not reported here. The ability to inject and propagate the particles at the design concentration, in a sand pack of the appropriate permeability at the injection temperature was confirmed as part of the pre-job testing. b. c. d. Conclusions Tests completed in support of the Minas field trial of Bright Water allowed the following conclusions to be made. 1. The Bright Water kernel particles could be injected into packs and cores of permeability between 124 and 3400 mD. The particles could be popped on heating and give rise to a build up of viscosity in bottle tests. In packs and cores this was noted both as a Resistance Factor and as a Residual Resistance Factor. 2. ( SPE 89391 9 J.. The RF /RRF achieved was dependent on the particle concentration and the porous medium studied. The data gathered in the laboratory tests could be used to design the treatment in the field. Cost Effective Waterflood Control", J Petroleum Science and Engineering, 1, 33-43, 1992. Originally in Proceedings of the 6th European lOR-Symposium, Stavanger, Norway, 329-335; 21 st -23rd May, 1991. 11. Ranganathan, R. et aI, "An Experimental Study of the In Situ Gelation Behaviour of a Polyacrylamide / Aluminum Citrate "Colloidal Dispersion" Gel in a Porous Medium and its Aggregate Growth During Gelation Reaction", paper SPE 37220 presented at the 1997 SPE International Symposium on Oilfield Chemistry, Houston, Texas, 18 - 21 February 1997. 12. Kin Tai Chang, Harry Frampton and James C. Morgan. "Method of recovering hydrocarbon fluids from a subterranean reservoir", United States Patent 6454003, 24th September 2002. 13. ASTM D4404-84 (1998) el, "Standard Test Method for Determination of Pore Volume and Pore Volume Distribution of Soil and Rock by Mercury Intrusion Porosimetry" . 14. Lynch, E.J. and MacWilliams, D.C. "Mobility Control with Partially Hydrolysed Polyacrylamide - A reply to Emil Burcik", SPE 2776 reprinted in Journal of Petroleum Technology, 1247 -1248, October 1969. 15. Coberley, C.l and Wagner, E.M. "Some considerations in the selection and installation of gravel pack for oil wells", AIME Technical publication 960, Petroleum Technology, August 1938, 1 - 20. 16. Veizen, I.F.G.V. and Leeriooljer, K. "Impairment of a water injection well by Suspended Solids: Testing and Prediction", paper SPE 23822 presented at the SPE International Symposium on Formation Damage Control, Lafayette, LA, February 26th - 27th 1992. 17. American Petroleum Institute, "Recommended practices for evaluation of polym,ers used in enhanced oil recovery operations", Recommended Practice 63 (RP63) First Edition, June 1, 1990. 18. Wojtanowitz, A., Krilov, Z. and Langlinais, lP. "Oilfield completion fluid solids interaction with an unconsolidated oil reservoir", Particulate Sci and Tech.,~, 173 - 192, 1987. 19. Soo, H. and Radke, l "Flow of dilute, stable liquid and solid dispersions in underground porous media" AIChE Journal, 31 (11), 1926 - 1928, 1985. 20. Vitthal, S. and Sharma, M.M.. "A Stokesian Dynamics Model for Particle Deposition and Buildup in Granular Media", Journal of Colloid and Interface Science, 153(2), 314 - 336, October 1992. 4. Acknowledgements Thanks are due to the member of the development team over the period of preparation for the Minas field trial. Acknowledgement is also due to Kemow Analytical Technology for running some of the pack and core tests used here and Professor Martin Snowden of the University of Greenwich, UK for the Scanning Electron Micrographs. Finally thanks are due to our respective companies for permission to publish this work. References 1. Pritchett, l et aI, "Field Application of a New In-Depth Waterflood Conformance Improvement Tool", paper SPE 84897 presented at the SPE International Conference on Improved Oil Recovery in Asia Pacific, Kuala Lumpur, Malaysia, 20 - 21 st October 2003. 2. Pye, David l, "Improved Secondary Recovery by Control of Water mobility", paper SPE 845 Journal of Petroleum Technology, August 1964 reprinted in Petroleum Transactions, 911 - 916, August 1964. 3. Putz, A. G., Bazin B. and Pedron, B. M. "Commercial Polymer Injection in the Courtenay field, 1994 update", paper SPE 28601 presented at the 69th Annual Technical Conference and Exhibition of the Society of Petroleum Engineers, New Orleans, Louisiana, 25th - 28th September 1994. 4. Koning, E. l L. and Mentzer, Eoo "Evaluation of a pilot polymer flood in the Marmul field, Oman", paper SPE 18092 prepared for presentation at the 63rd Annual Technical Conference and Exhibition of the Society of Petroleum Engineers, Houston, Texas, 2nd - 5th October, 1988. 5. Demin, W., Lanshui, Z., Jiecheng, C. and Junzheng, W. "Actual Field Data Show that Production Costs of Polymer Flooding can be Lower than Water Flooding", paper SPE 84849 presented at the SPE International Improved Oil Recovery Conference in Asia Pacific, Kuala Lumpur Malaysia, 20 - 21 st October 2003. 6. Edinga, K. l, McCaffery, F. G. and Wytrychowski, 1. M. "Cessford Basal Colorado A Reservoir - Caustic Flood Evaluation", Journal of Petroleum Technology, December 1980, 2103 - 2110. 7. Wyatt, K., Pitts, M.J., and Surkalo, H. "Mature Waterfloods Renew Oil Production by Alkaline-Surfactant- Polymer Flooding", paper SPE 78711 presented at the SPE regional meeting, Lexington, Kentucky, USA, 23 - 25 October 2002. 8. Carlay, P. and Delamaide, E. "Status and Outlook of the polymer flooding process", Journal of Petroleum Technology, 198-199, March 1996. 9. Mack, lC. and Smith lE. "In-Depth Colloidal Dispersion Gels Improve Oil Recovery Efficiency", paper SPE/DOE 27780 presented at the SPE/DOE 9th Symposium on Improved Oil Recovery, Tulsa, Oklahoma, 17 - 20th April 1994. 10. Fletcher, A.lP., Flew, S., Forsdyke, LN., Morgan, lC., Rogers, R. and Suttles, D. "Deep Diverting Gels for very ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg %1i 11,,~)C4 DATE: January 8, 2004 P. I. Supervisor SUBJECT: Mechanical Integrity Tests FROM: Jeff Jones 8P{XA Petroleum Inspector 8, J Pads 8-12,8-18, J-11, J-15 MPU Milne Point Field NON- CONFIDENTIAL 4 P 4 P 4 P 4 P Type Test Interval M= Annulus Monitoring 1= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details January 8, 2004: I traveled to BPXA's Milne Point Field wells B-12, B-18, J-l1 and J-15 to witness MITis. Lee Hulme was the BPXA representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with each well passing the MIT. Four well houses were inspected with no exceptions noted. Summary: I witnessed successful MITis on BPXAls Milne Point Field wells B-12, B-18, J-ll and J-15. Four well house inspections conducted, no exceptions noted. M.I.T.'s performed: ~ Number of Failures: Q Total Time during tests: 6 hrs Attachments: cc: .' 8)(ÇA[~~IEI JJ~N 2 §~ 2004. MIT report form 5/12/00 L.G. MIT MPU 8-12,8-18, J-11, J-151-8-04 JJ.xls 1/15/2004 f , f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test :5Ef2- Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us )/~/O4 OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ap Exploration - Alaska Milne Point Unit / a-pad & J-pad 01/08/04 Packer Depth Pretest Initial 15 Min. 30 Min. Well B-12 Type Inj. P TVD 6,998' Tubing 2,140 2,140 2,140 2,140 Interval 09:38 P.T.D. 1850800 Type test P Test psi 1,750 Casing 550 1,800 1,760 1 ,750 P/F Pass Notes: 1 bbls diesel to 1800 OA 650 750 750 750 Bled back to 500 Well B-18 Type Inj. P TVD 6,854' Tubing 2,550 2,550 2,550 2,550 Interval 10:40 P.T.D. 1852290 Type test P Test psi 1,714 Casing 500 2,200 2,180 2,170 P/F Pass Notes: 2 bbls diesel to 2200 OA 300 480 480 480 Bled back to 500 Well J-11 Typelni. P TVD 3,913' Tubing 1,920 1,920 1,920 1,920 Interval 13:45 P.T.D. 1941140 Type test P Test psi 1,500 Casing 740 2,600 2,550 2,550 P/F Pass Notes: 1.2 bbls diesel to 2600 OA 650 750 750 750 Bled back to 500 Well J-15 Type Inj. P TVD 3,839' Tubing 1,180 1,180 1,180 1,180 Interval 12:45 P.T.D. 1991070 Type test P Test psi 1,500 Casing 500 2,025 1,980 1,950 P/F Pass Notes: .7 bbls diesel to 2025 OA 650 750 750 750 Bled back to 500 Well. Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) 8(ÇÅ~~E~) JAN 1 4~ 2004 MIT Report Form Revised: 06/19/02 2004-01 08_MIT _MPU_J-15.xls NOTE;S: ALL MEASUREMENTS ARE FROM KDB OF NABORS RIG NO. 27E KDB - SL = 59' KDB - GL = 2. MAX. ANGLE = 38'@ 3700' MD 3. K.O.P. = 3000' 4. SLANT HOLE: YES 5. MIN. ANGLE = 29.75° AT 6800' MD 6. TREE TYPE: FMC 3 1/8" APl 5000# WITH `3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO 'D' NIPPLE (2.75" ID) 8. COMPLETION FLUID: 8.6 PPG NaCI BRINE W/12% MeOH PERFORATIONS: 12 SPF AT 120' PHASING MK-1, MK-2 7724'-7757' MD 7155'-7163' TVD (BASED ON DIL LOG OF 5-10-85) CONOCO INC. ANCHORAGE DIVISION WELL No. COMPLETION MILNE POINT B-12 SKETCH UNIT (I) APl No.: 50-029-21.3,38 PERMIT No.: 85-80 COMPLETED: 5/14/85 LAST WORKOVER: 9/,3/91 FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE ~3 1/2", 9.3// L-80, 8rd EUE (2.992" ID) 569' CAMCO TRDP-IA-SSA-SCSSV (2.812" ID) 7596' CASING R.A. MARKER (~qqgl T-Vp )'7%o Yes1- ~°s.$-- 7575' OTIS "HVT" PKR 1 JT 3 1/2", 9.5#, L-80, 8rd TBG SEAL ASSEMBLY 7619' DOT PBR 7640' DOT 'NB' HYDRAULIC PACKER (2.89" ID) 7685' CAMCO 'D' NIPPLE (2.75" ID) 7697' TUBING TAIL 7773' TOP OF FISH 7920'--7", 26 LB/FT L-80 BTRS (6.276" ID, 6.151" DRIFT) I APPROVED BY: HDS DATE: 0,3/26/92 DRAFTED BY: SdN CAD FILE: WCOB12 · =. March 3, 1992 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 Mr. Blair E. Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell, Production logs were run in the Milne Point Unit B-12 well January 21st as part of the continuing effort to resolve annular pressure problems in the Milne Point injectors. The tubing in the well was displaced with high pressure nitrogen in an attempt to create a noise or temperature anomaly at the leak point(s) large enough to be detected by temperature and noise logging tools. Logs were run immediately after displacing the tubing. Special emphasis was placed on taking detailed measurements in and near all pieces of completion jewelry: the packer, packer seals, nipples, SCSSV, etc. The results of the logs are summarized below. i · Temperature logs indicate possible collar leaks near 1940' and 2920'. Leaks were not detected at these depths by the noise logs. · Noise logging indicated a possible leak near the SCSSV assembly, but results were not conclusive. The noise anomaly is most probably due to additional turbulence induced by the reduced ID through the valve. . No leaks were detected in or near the completion packer assembly by either the temperature or noise logs. While we are disappointed the results were not more conclusive, we feel more confident that properly-engineered tubing/packer replacements will resolve the majority of our problems. The existing 3-1/2" Buttress thread tubing strings will be replaced with 3-1/2" or (preferably) 2-7/8" 8rd EUE tubing with API modified couplings and special thread sealant. It does not appear that expensive premium threaded tubulars will be required. The existing packer/seal assemblies will be left in place but new packers with static seals will be run above them. The first injector we plan to test with this new arrangement will be the MPU C-8 well. We are planning to work this well over this Spring, with the exact schedule dependant upon rig availability. (Our workover rig is currently stacked awaiting enough approved projects to justify a start-up.) The_r~maini~ wells will be worked over following the 0-8. Alaska 0il & Gas Cons. C0mm[ssior'~ Anchorage' I have included log excerpts covering both temperature anomalies. Attachment One is a Gamma Ray/Pressure/Temperature log showing the temperature anomaly near 1940'. Attachment Two is an excerpt from the same log showing the anomaly near 2920'. We will continue to keep the Commission informed of our progress in this area. Please give me a call at 564-7621 if you have any questions or need further information. Sincerely, J. H. Andrew Sr. Production Engineer .80000 GR(GAPI! 0.0 100.00 PT EM(D__EG.~) 0.0 200.00 CCL -19.00. 1.0000 / · · ~ V'- I<- -- i! S/ I CCL ---> i SKET 1900 2OOO 2100 2200 o.o ATTACHMENT ONE ~;.-o-do- .......... _m~.~_ ¢_~.,'_~ ................ I 0000 PT E t',~ D E G_..~F) .............. o.o 1 o oo( __ __ PPRE(PSIA! __ ,,,..,, \. %. 3.0 -19.00 PTEM(D EGF.) PPRE(PSIA) CCL SKET 80000 200.00~ 200.00 1,0000 SKET A'i-I'ACHMENT TWO l P__DTIE(D_FiF) Oi -1 .ooo 1 _oo _ PTErvl(D EGF) ........ 70 ................ ~o,ooot COLLARS CP 32.2A FILE 24 1 2"/100' J -' 2700 28OO 2900 3OOO 21-JAN-1992 21:19 i ; __ . I ' ; ; . ~: _ / _ I -,.. , J \! I SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLC~Y CORPORATION HOUSTON. TEXAS 77251-21 ?.~ PLEASE REPLY TO dAN Z 3 199~ SC,LUUSE,~E, WEL, sERV,CES ?ouch 340069 ?rudhoe Bay, AY, 99734-0069 ATTN: Bernie/Shelley Conoco, :[nc 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: LJnda Starr Gentlemen: Enclosed ore 3 BLp. rintsofthe Noice Log, Temp/Press, Run 1, 1/21/92 Company Conoco, Inc Well Miln.e Point Unit B-12 Field MJ lne POJ nt Additional prints ore being sent to: I BL prints Conoco, Inc 600 North Dairy Ashford Houston, TX 77079 Attn: George. Lamb, OF 2018 PER on: County North Slope State Al a.~ka 1 BL prints, 1 RF Sepia Chevron U.S.A. 11111 South Wi]crest Houston, TX 77099 ATTN: Michael QuJnn *(713/561-3673) I BL prints Conoco, Inc 1000 South Pine Ponco City, OK 74603 Attn: Glenn Welch, 7360 RDW /' Alaska Oil & Gas Conser~atJ / _i'_ ~°mmissi°n ) [ 3--00_1_ Poz_cupJne Drive / ~..At t n: John Bo_~3.~ / on prints The film is returned to Conoco, Linda Starr I BL prints, 1 RF Sepia OXY U.S.A. Inc 6 Desta Dr~v~_: guJt~ flor)2 MJ al!and, TX 79705 Attn: Jnhn~ C,m rrml *(9~ S/68~-58qS) prints prints RECEIVED dAN z ~ 1~- Alaska Oil & Gas Cons. Commission Anchorage Received b¥:J~~-~ ~ Date: We appreciate the privilege of serving you. SW$-- I 327 F OIl/CH (lt~L/3RF) Very truly yours. SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation shutdown__ Re-enter suspended well__ Alter casing Repair well Plugging_ Time extention __ Stimulate Change approved program Pull tubing __ Variance x Perforate __ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development 59' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit Service x 4. Location of well at surface 8. Well number 765' FSL, 920' FWL, Sec. 18, T13N, R11E, Umiat Meridian B-12 At top of productive interval 9. Permit number 2900' FSL, 715' FWL, Sec. 18, T13N, R11E, Umiat Meridian 85-80 At effective depth 10. APl number 2952' FSL, 698' FWL, Sec. 18, T13N, R11E, Umiat Meridian 50-029-21~(338 At total depth 11. Field/Pool 3016' FSL, 678' FWL, Sec. 18, T13N, R11E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 7934' feet Plugs (measured) true vertical 7314' feet Effective depth: measured 7833' feet Junk (measured) 7773' true vertical 7227' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 85' 13-3/8" 100 cuff Permf C 120' 120' Surface 4787 9-5/8" 424 bbl Cold Set III 4822' 4659' Intermediate 59 bbl Class G Production 7885' 7" 52 bbl Class G 7920' 7302' Uner Perforation Depth: measured 7724'-~.~ RECEIVED true vertical 7133' - 7163' NOV 2 6 '{(;J9 Tubing (size, grade, and measured depth) 3-1/2" 9.3#/ft, L-80, 7574' ~a_S}f~A ~J[ .& Gas Cons, G_0..ff~t Packers and SSSV (type and measured depth) Camco TRDP-1A SCSSV 569', Otis HVT Pkr 7575', BOT HB Pkr 7633' 13, Attachments Description summaryof proposal X Detailed operations program BOP sketch 14, Estimated date for commencing operation 15. Status of well classification as: N/A 16. If proposal was verbally approved Oil__ Gas __ Suspended Name of approver Date approved Service Waterflood Iniector 17. I hereby certif' 'that the ~oregoing is true and correct to the best of my knowledge. Signed ~ /~ /~J0~ J. H. Andrew Title Production Engineer Date Nov 19, 1991 FOR COMMISSION USE ONLY Conditions of approval:Plug integrity__N°tify Commission so representative may witneSSBoP Test Location clearance [Approval No. ~/__~ ~ Mechanical Integrity Test ~ Su--bsequent form required 10-~ Approved by order of the Commission LON~{,~ ~... S~/IITH Commissioner ---D - ...... :--~/~::::~ '- ~, ~ ~ / .-- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit B-12 Well The MPU B-12 well is an active water injection well. Pressure on the 3-1/2" x 7" production tubing-casing annulus is currently 3050 psig, equal to surface injection pressure. This is in excess of the 500 psig maximum pressure guideline established by the Commission for continuous operation of injection wells. Conoco requests a variance to allow injection to continue while diagnostic work is performed. This work is necessary to determine the exact source of pressure communication. The MPU B-12 well was worked over in August along with the MPU B-14 and MPU B-17 injectors. All had annular pressure problems prior to the workovers. Leaking tubulars (buttress threads) were initially suspected. The entire tubing string was replaced in each well with new 8rd tubing. New packer/seal assemblies were also run in the B- 12 and B-14 in case the original packer seals were not holding. Pressure developed in the production casing annulus almost immediately after the B-12 well was brought back on line, even though it had successfully passed a test for mechanical integrity following the workover. Pressure has not returned in either the B- 14 or B-17 wells. It is not known why workovers were successful in the B-14 and B-17 wells, and not in the B-12 well. A noise log was run in the B-12 immediately prior to the workover to attempt to identify the leak path. This log was run while the well was on active water injection. A leak was not detected. The wellhead was also tested before and after the workover. No leak paths were found. Our current plan is to displace the water in the production tubing with nitrogen and relog the well. The nitrogen gas phase will allow a much smaller leak to be detected. Annular pressure in the B-12 well can be bled to 500 psig in less than 15 minutes with under four barrels of fluid recovered. A positive determination of the source of the pressure communication is needed before any additional workovers are performed on Milne Point water injectors. Additional testing also is being planned in the interim period to reconfirm annular fluids are not in communication with uncased hole. We will continue to keep the Commission informed of the results of all testing. Oil & 6~s GoDs. Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 September 25, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Report of Sundry Well Operations Dear Mr. Johnston: Attached please find the Report of Sundry Well Operations for Well B-12. The well is located on the Milne Point Unit. If you have any questions or require additional information please contact me at 564-7617. Yours very truly, Bob Soptei Environmental Coordinator RJS(bgs) attachments CC Occidental Petroleum Chevron Inc. B-12 Well File C :\DATA\WP51 \RJS\AO GCC 18.RJS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing__X Alter casing __ Repmr well __ Perforate __ Other __ 2. Name of Operator CON'OCO [N'C. 3. Address 3201 "C" St., Ste. 200 Anchorage, A16ska .99503 4. Location of well at surface 765' FSL & 920' FWL, At top of productive interval 2900' FSL & 715' FWL, At effective depth 2952' FSL & At total depth 3016' FSL & Sec. 18, Sec. 18, 698' FWL, Sec. 18, 678' FWL, Sec. 18, T13N, T13N, T13N, T13N, 5. Type of Well: Development Exploratory Stratigraphic Service RllE, U.M. RllE, U.M. RilE, U.M. RilE, U.M. 6. Datum elevation(DForKB) 59' KB feet 7. Unit or Property name Milne Point Unit 8. Well number B-12 9. Permit number/approval number 85-80 10. APl number 50-- 029-21338 11. Field/Pool Kuparuk River 12. Present well condition summary Totaldepth measured 7934' true vertical 7314' Effective depth: measured 7833' true vertical 7227 ' feet feet feet feet Plugs (measured) Junk(measured) 7773 ' Casing Length Size Structural Conductor 85 ' 13-3/8" Surface 4787' 9-5/8" Intermediate Production 7885 ' 7" Liner Perfora[~ondepth: measured 7724' - 7757' Cemented Measured depth True vertical depth 100CF Perm 120' 120' 424 bbl ColdSetIII 4822' 4659' 59 bbl Class G 52 bbl Class G 7920' 7302' RE6EIV[D true vertical 7133' - 7163' O~;T u 1 1991 Tubing (size, grade, and measured depth) 3-1/2" L-80 7698' A/ask 0il & 6as 6.0ns. Anchora Packers and SSSV (type and measured depth) Packer - BOT "HB" ~ 7633' SCSSV - Camco T~P-1A ~ 570' -OTIS "HVT" Versa - Trieve ~ 7575' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation RepresentativeDailyAverageProductionorlnjectionData OiI-Bbl Gas-Md Water-Bbl CasingPressure 3425 2200 3056 800 ~bingPressure 3000 3000 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-~04~ev~36/15/88 Title Senior Production Foreman Date 9/21/91 SUBMIT IN DUPLICATE MPU B-12 WORKOVER SUMMARY (SEPT 1991) DAY OPERATION: 9/1 MONITOR SITP TO DETERMINE RESERVOIR PRESSURE. 9/2 RU HOT OIL, TEST LINES TO 3500 PSIG, & PUMP 68 BBLS DIESEL SOAK AND LET STAND FOR ONE HOUR. FLOW BACK 3 TUBING VOLUMES (210 BBLS) AT 2.5 BPM INTO FRAC TANK VIA HARDLINE WITH CHOKE (TESTED TO 3000 PSIG). PUMP SECOND 6,8 BBL OIL SOAK AND R/U SLICK LINE UNIT. RIH WITH BRUSH AND GAUGE RING TO CAMCO D NIPPLE. POOH W/ SLICKLINE. FLOW BACK 2 TUBING VOLUMES (140 BBLS) AT 2.5 BPM INTO FRAC TANK. HOT OiL PUMP 20 BBLS METHANOL FREEZE PROTECTION & R/D. RIH W/ & SET POSITIVE PLUG IN CAMCO D NIPPLE AT 7685'. POOH & R/D SLICKLINE UNIT. INSTALL 2 WAY CHECK VALVE IN TUBING HANGER. MIRU WORKOVER RIG. N/D TREE, N/U BOPE, & TEST BOPE 5000 PSIG & 500 PSIG. 9/3 PU & RELEASE SEAL ASSEMBLY FROM BOT PBR @ 7626'. POOH L/D 242 JTS. OF 3.5", 9.3#, L-80, BTRC TUBING. TIH W/ REDRESSED BOT SEAL ASSEMBLY, OTIS HVT HYDRAULIC SET PACKER, & CAMCO SCSSV ON 3.5", 9.3#, L-80, 8RD EUE TUBING. DISPLACE 11.5 PPG WORKOVER BRINE W/ 8.4 PPG SOURCE H20 TREATED FOR SCALE AND CORROSION. FREEZE PROTECT ANNULUS W/ 60 BBLS DIESEL & TUBING W/ 20 BBLS METHANOL. STING INTO BOT PBR W/ SEAL ASSEMBLY -- VERIFY W/ PRESSURE TEST ON THE BACKSIDE. SET OTIS HVT PACKER SET @ 7633' RKB & HOLD FOR 15 MINUTES W/ ZERO PRESSURE ON BACKSIDE TO CONFIRM NO TUBING LEAK. RELEASE PRESSURE & PERFORM MECHANICAL INTEGRITY TEST W/ 2000 PSIG ON THE 3.5" X 7" CASING ANNULUS FOR 30 MINUTES -- MONITORED ZERO TUBING PRESSURE WHILE SHUT IN ON TIW VALVE. N/D BOPE, N/U & TEST TREE TO 5000 PSIG, INSTALL BPV, & MOVE RIG. 9/4 REMOVE BPV, MIRU SLICKLINE & RETREIVE POSITIVE PLUG F/ CAMCO D NIPPLE @ 7685'. ............................. END OF REPORT. STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION C01~I'M ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well ~ Alter casing __ Repair well __ Plugg~.ng __ Time extension __ Stimulate __ Change approved program __ Pull tubing _x_. Variance __ Perforate __ Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco ]'nc. Development__ 59' 1CB feet Exploratory ~ 3. Address 99503 -Stratigraphic __ 7. Unit or Property name 3201 C Street, Suite 200, Anchorage, AK Service_X_ Milne Point Unit 4. Location of well at surface 8. Well number 765' FSL and 920' FWL, Sec. 18, 'T13N, RllE, U.M. B-12 At top of productive interval 9. Permit number 2900' FSL and 715' FWL, Sec. 18, T13N, RilE, U.M. 85-80 At effective depth 10. APl number 2952' FSL and 698' FWL, Sec. 18, T13N, RllE, U.M. 50-- 029-21338 At total depth 11. Field/Pool 3016' FSL and 678' FWL, Sec. 18, T13N, RllE, U.M. Kuparuk River 12. Present well condition summary Total depth: measured 7934 ' feet Plugs(measured) true vertical 7314 ' feet Effective depth: measured 7833 ' feet Junk(measured) 7773 ' true vertical 7227 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 85 ' 13-3/8" 100 CF PER~ 120' 120' Surface 4787' 9-5/8" 424 bbl Cold Set III 4822' 4659' Intermediate 59 bbl Class G Production 7885' 7" 52 bbl Class G 7920' 7302' Liner Perforation depth: measured 7724' - 7757' true vertical 7133' - 7163' Tubing (size, grade, and measured depth) 3-1/2" L-80 7698' ; Packersand SSSV (type and measured depth) Packer -BOT "HB" @ 7640' :- SCSSV - CAMCO TRDP-1A @ 1788' 13. Attachments Description summary of proposal .Z,.. Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: December 5, 1990 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Waterflood In-iector 17. I hereby c( tify that tJ~e foregoing is true and correct to the best of my knowledge. Signed \ I,/t/I ,/'~t,_.~¢~ J.H. Andrew Title Production Engineer Date 11/26/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness,I Approval No. ¢~ _ ~:)~/ Plug integrity ~ BO, P/Test __ Location clearance ~ Subsequent required 10- ,z~._~ ~ - Mechanical Integrity Test ._~ form ORIGINAL SIGNED BY Approved Copy LONNIE C. SMITH Returned Approved by order of the Commission ~ ,,'~t~/g:~(~ . Commissioner Date SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 (,~ MPU B-12 Workover Procedure Summary · · · 4. 5. 6. 7. · 9. 10. 11. Monitor SITP to determine reservoir pressure. RU slickline. Set a pump-through plug in the Camco D nipple at 7685'. RD slickline. MIRU workover rig on well. ND tree, NU and test BOP's. PU to release sting out of BOT PBR assembly at 7626'. POOH and LD 3-1/2" production tubing. TIH with redressed PBR seal assembly, new 3-1/2" EUE 8rd production string and new SCSSV. Hydrotest connections while TIH. Freeze protect. Space out, land and test hanger. ND BOP's. NU and test tree. RU slickline. GIH and pull tubing plug. RD slickline. Return well to waterflood injection service. SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 77:)5 1 -2 175 OCT ! ? 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~$E REPLY TO SCHLUMBERGER WELL SER¥1CES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen' Enclosed are2 BT, prints of the Injection Profile Spinenr Survey, Run 1, Company CONOCO, Inc. Well Milne Point Unit B-12 lO/13/o~' Field MJ_lne PoJ. nt Additional prints ore being sent to: 1 BL prints CONOCO,. Inc. 600 North Dairy Ashford Houston, TX 77079 A~tn: George Lamb - OF 2018 PER County Nnrth Slope I State Alaska _l_BL_prints, 1 RF Sepia CONOCO; ThC 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. _6 De~a Drive Midland, TX 79710 A~tn: John Carrol *(~15/685-5600) _J~_]~]~_prints, 1RF Sepia Chevron U.S.A. 6001BDllinger Canyon Road _S_an Raman, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) 1 BL~ Se~ ml~a 0il & Gas Conservati~ /CommissJ. on ~ ~001 Porcupine Drive ~orage, AK 99501 / Attn: John Boyle The film is_returned to Conoco, Log Library. prints prints prints ~' Alaska 0il & cas Cor~s. uu,,i,,,,~ ..... Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SWS-- 1327-F Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. ACTIVE: -. B-3, B-4A, B-6, B-9, B-i0, B-ii, B-13, B-i5, B-!6, C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, B-21, B-22 C-!7, C-i8 All active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the ~hut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. ~ ~.._. ~ ~. ~'~ ~'~ ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-il, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure° When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will b~ set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. If you have any questions on the shutdo~m procedure please contact Don Girdler at 564-7637. Yours very truly, ~ ~~.~ ~~P. Painter /~v { s ion Manager STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION COMk~,.oSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~- Suspend _~ Operation Shutdown Re-enter suspended well ~ Alter casing ~ Time extension .._' Change approved program ~% Plugging ..-I Stimulate ~., Pull tubing ~ Amend order ~ Perforate ~ Other ~_.' 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. - 59' KB feet ress 6. Unit.qr~ Prop._.erty nam_.e 3. Add3201 C Street, Ste. 200, Anchorage, Alaska 99503 ~tl~ne ~olnt unit 4. Location of well at surface 765' FSL, 920' FWL, Sec. At top of productive interval 2900' FSL, 715' FWL, Sec. At effective depth N/A At t~t~(~Pt¢sL, 678' FWL, Sec. 18, T13N, RllE, U.M. 18, T13N, RllE, U.M. 18, T13N, RllE, U.M. 7. Well number B-12 8. Permit number 85-80 9. APl number 50-- 029-21338 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 7964 7340 feet feet Plugs (measured) Effective depth: measured true vertical N/A feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" 4786' 9 5/8" 7886' 7" 7724'-7757' measured To Surface 483 bbls 52 bbls Measured depth 115' 4822' 7920' True Vertical depth 115' 4659' 7302' true vertical 7133'-7163' Tubing (size, grade and measured depth) 3!~", L-80, 7699' T.R. SCSSV @ 1788' Packers and SSSV (type and measured depth) ; Ret. Pkr. @ 7640' 12.Attachments Description summary of proposal ~ Detailed operations program~.,~ BOP sketch 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~^ ~... Title Sr. Production Engineer Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ? I ? .~ Plug integrity ~ BOP Test ~ Location clearance Approved by Commissioner ! by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 27, 1986 ',,~ ,Vi I JI F-~ f-~ 7:. . :'._.:.' .... ,~1 I ~-' ' .......... I' - :f , .. 7.. State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Attached are daily drilling recaps for MPU wells B-5A, B-8, B-12, B-14, B-18, B-19, B-21, C-10, C-ii, C-12, C-18. Completion reports were submitted by our letter of August. 18, 1986. If you should have any questions please call Charles Taylor at 564-7606. Yours very truly, E. D. Wilson Division Administrative Manager CLT/vv Well File RECEIVED AUG 2 8 1986 Ala~-ka 0il & Gas Conn. Commt~slou Anchorage Kuparuk River Field - ~?orth Slope Borough, Alaska W.I. - 52.05955% Milne Pt. B No. 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 AP1 No. 50-029-21338. Ak. Permit No. 85-80. Elevation' 59' KB Location: 765' FSL, 920' ~L, Sec. 18, T13N, RILE, U.M. 5-2 - Move pits, motor complex, sub base, pipe sheds, diesel storage &'heaters. Position over wellsite & RU. NU diverter line. PU BHA, test ~D. Function test diverter. Drlg. f/120' to 315'. ACCEPTED RIG @ 2030 HRS. on 5-1-85. Nabors #27-E (0-1-0) Drlg. Foreman - S. Brady Weather: Temperature: 40/-4° Wind: SW 13 knots Visibility: 20 miles Kuparuk River Field - North SI. ope Borough, Alaska W.I. - 52.05955% Milne Pt. B No. 12 - CONFIDENTIAL (8,]54' - Kuparuk River) AFE 10-61-1114 5-3 - Drlg. f/315' to 1687'. POOH, 1500 'psi pressure drop. Found washed bit nozzle. TIH. Drlg. f/1687' to 3003'. POOH. PU Navidrill. Orient M~D & TIH to 3003'. Surveys: pepth Angle 468' 0.2° N37W 1444' 0.6° S53W Nabors #27-E -(0-2-0) Mud Wt.: 9.8 ppg V~ Weather: Temperature: 0°/0° Wind: Direction Depth Angle Direction 2321' 0.4© N01W 2799' 1.4° S46W Drlg. Foreman - S. Brady 43 Visibility: 1/2 mile K~paruk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. B No. 12 - CONFIDENTIAL (8,154' - Kuparuk Ri~er) AFE 10-61-1114 5-4 - Drlg. w/Navidrill f/3003' to 3640'. POOH for BHA change. LD Navidrill, PU jetting assembly & new bit. TIH to 3640'. Drlg. f/3640' to 4000'. Surveys: Depth Angle Direction Depth ~ngle Direction 2938' 1.6° N 3514' 13.7° N01E 3038' 2.3° N33E 3546' 14.6° N01E 3133' 4.1° N17W 3656' I6.9© N01E 3229' 6.2° N08W 3750' 18.3° N04E 3325' 8.5° N03W 3846' 20.0° N04E 3420' 11.0° N03W 5-5 - Drlg. f/4000' to 4527'. POOH, change BHA & bit. TIH to 300', cut & slip drlg. line. T1H to 4528'. Drlg. f/4528' to 4865'. Make 15 stds., short trip. Circ. & cond. mud. POOH, strapping pipe. Surveys: Depth An~le Direction Depth ~n~le Direction 3941' 21.8° N04E 4419' 34.4° N06E 4038' 23.7~ N04E 4482' 36.6° N07E 4134' 26.4~ N07E 4579' 37.1° N07E 4227' 28.4° NO6E 4675' 38.0© N08E 4322' 31.2° N06W 4771' 38.0° N08E 5-6 - POOH f/4865'. LD BHA. RU & run 122 jts. of 36#/ft K-55 9-5/8" Butt. csg. Shoe @ 4822', top of float @ 4741'. Ran 44 centralizers. Full returns throughout job. MU landing jt., RD csg. crew & RU cementers. Circ. 1~ csg. volumes w/9.9 ppg mud while reciprocating pipe, 15 stks. Pump 40 bbls. of 11 ppg Zerogel preflush, drop plug & pump 10 bbls. water followed w/424 bbls. of 12.3 ppg Cold Set III w/4 lb/sk gilsonite, followed w/59 bbls. of 15.8 ppg Class "G" w/3% NaC1 & 0.2% D-6. Drop plug, pump 10 bbls. water displaced w/364 bbls. of 9.9 ppg mud. Bump plug & press, up to 2020 psi. Release press., floats held. Lost returns for last 10 bbls. of displacement. Cmt. returned to surface, wt. 12.2 ppg. CIP @ 1910 hrs. ND diverter & wash cmt. f/drlg, nipple & ROP. Remove landing jnt. XO from hanger & install trash barrier, screw~on cap & split speed head. Torque up speed head to 13,000 ft/lbs. NU adapter flange, BOP, choke line & flowline. Nabors #27-E (0-5-0) Drlg. Foreman - S. Brady Mud Wt.: 10.3 ppg Visc.: 45 Weather: Temperature: 18°/-5° Wind: SW 18 knots Visibility: 25 miles Mtlne Pt. B No. 12 - ~_ :~FIDENTIAL (8,154' - Kuparuk Rzvar) AFE 10-61-1114 5-7 - Test BOP(s), upper & lower pipe rams, & blind rams to 5000 psi, test annular to 3000 psi, test choke manifold, HCR valve, TIW, upper & lower kelly cock & inside POP to 5000 psi. Install kelly spinner. Strap BHA, PU BHA, orient ~. TIH & tag Float collar @ 4739'. Test Csg. to 1500 psi, lost 150 psi. Drlg. float plugs & shoe to 4885'. Perform leak-of test equivalent to a 12 ppg mud. Drlg. survey & orient from 4885' to Surveys: pepth Angle 4953' 37.9° 5111' 32.1° 5270' 30.6° Nabors #27-E (0-6-0) Mud Wt.: 9.5 ppg Direction N6E N7E N5E Visc.: 40 Drlg. Foreman - S. Brady Weather: Temperature: 15°/-4° Wind: ENE 10 knots ~uparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. B Mo. 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 5-8 - Drlg., survey, and orient from 5440' to 6877'. Surveys: pepth An$1e Direction 5427' 31.1° N2W 5586' 31.1~ N8W 5745' 32.0° N10W 6030' 31.6~ N12W 6349' 31.1° N1W 6507 31.0 N14W Nabors #27-E (0-7-0) Mud Wt.: 10.2 ppg Visc.: 40 Visibility: 15 miles Weather: Temperature: +16°/+4° Wind: ENE 5 knots Visibility: 1~ miles Kuparuk River Field - North Slope BOrough, Alaska W.l. - Mi]ne Pt. B No. 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 5-9 - POOH from 6877' for bit change. Orient MWD, TIH to 6877'. Drlg. from 6877' to 7750'. Surveys: Depth Angl~ Direction 6792v 30.6° N12W 7078' 30.9o N12W 7396' 30.8o N17W Nabors #27-E (0-8-0) Drlg. Foreman - S. Brady Mud Wt.: 10.4 ppg Visc.: 42 Weather: Temperature: 21°/8° Wind: ENE 8 knots Visibility: 7 miles Kuparuk River Field - North Slope BoroughS--Alaska W.I. - 52.05955% ~ilne Pt. B No. 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 5-10 - Drlg. from 7750' to 7924'. Make 20 std. short trip to 6124". Hit tight spot, Ream from 7820' to 7924'. Circulate & condition mud. POOH from 7924'. LD ~B~D & Navidrill. RU to log. Run DIL-CNL-SFL-LDT-GR to 7745'. Tools would not fall to bottom. POOH, remove centralizers & add sinker bars. TIH to 7745'. Tools would not fall. Attempt to work to bottom. No success. POOH. Wireline pulled out of rope socket w/3500# line pull @ 7700'. POOH w/wireline. PU double bowl overshot w/grapple to catch 2-5/16" fishing neck & 3-1/2" tool body. Tag fish @ 7740', set 13,000~ on too].. Start pump, string holding pressure. POOH slow from 7740'. Retrieve fish. TIH w/bit. Nabors ~27-E (0-9-0) Drlg. Foreman - S. Brady Mud Wt.: 10.5 ppg Visc.: 44 Weather: Temperature: 20°/13° Wind: NE 5 knots Visibility: 1 mile Drlg. Foreman - S. Brady Kuparuk River ~ id- North Slope Borough, Alasi~. W.I. - 52.05955% Milne Pt. B No.~ 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 5-11 - POOH w/fish. LD fish. TIH to 7700'. Ream f/7700' to 7924'.' Dr]g. f/7924' to 7964'. Short trip f/7964' to 7014'. Pump high visc. sweep & circulate. POOH from 7964'. Pulled first 10 stds. slow. ND bell nipple & flow line in order to right fallen diverter. PU diverter & stand back. NU bell nipple & flow line. RU & run logs. Run GR, DIL, & SP from 7962' to 4820'. Porosity logs from 7962' to 7500'. CNL & GR from 4822' to 200'. RD EL. TIH to 7964'. Short trip f/7700' to 7964'. Circulate. 5-12 - Finish TIH to 7964'. Make 5 std. short trip f/7964' to 7514'. Circulate bottoms up. POOH LD drill pipe & BHA. Pull wear bushing. Chg. pipe rams & RU csg. crew. Run 200 jnts. of 7" 26# L-80 csg. w/ burrs threads Float shoe @ 7920' float collar @ 7838' ECP @ 7778' · · , , , 2 pup jnts., top at 7635'. RA marker @ 7596'. Full returns throughout job. MU hanger, packoff, & landing int., PU circulating head & circulate.. Pump 40 bbl. pr,flush of 12 ppg Desco& water. Pump 10 bbl. H_O Drop ~lug, pump 52 bbls. 15.8 pp§. class C w/0.8Z D-19, 0.25% R-S~&~0.1Z D-6. Drop plug, displace w/B00 bbl. 9.6 ppg. NaC1 brine. Bump plug & inflate ECP w/2800 psi.; floats held; full returns throughout job; CIP @ 0400 hrs. RD cementers, backout landing joint, RU Camco E-line. 5-13 - Make gyro & gamma ray run w/Camco. RU & run csg. guns & PKR w/243 juts. of 9.2# L-80 butrs, tubing w/butrs. Proposed perf interval 7724' to 7760'. Proposed pkr.depth=7730'. PU hanger & landing jnt. Change out hanger & XO due to bad threads· Land hanger & lockdown. Run gamma correlation w/Camco· RD Camco E-line & add 7' of pups to tubing string. Land hanger & lockdown. Pressure up on tubing to close circ. vent. Open production vent & inflate packer· Able to pump in tubing w/annulus open & hold 2500 psi. Unable to hold pressure on backside w/tubing open, immediate & full returns· Packer ~pparent]y not set. Awaiting arrival of Otis unit to install positive check in D-Nipple in order to isolate problem. RU Otis. Nabors #27-E (0-12-0) Dr].g. Foreman - S. Brady Mud Wt.: 9.6 ppg Visc.: &2 Weather: Temperature: 17°/-2~ Wind: NE 10 knots Visibility: 15 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. B No. 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 5-14 - RU Otis. TIH w/C.A, blanking plug & set in Camco D-nipple. Circ. into 7"x3~" annulus recieving returns out of tubing. TIH w/Otis & retrieve blanking plug. PU 2 jts. of 3~" & TIH to tag pkr. @ 76~0' (10' below setting pt.). POOH & retrieve PBR seal assembly· Leaving PBR barrel, pkr. vents, & guns in hole. TIH-w/spiral grapple. Fish taking wt. @ 7715'. POOH. Fish retrieved. LD pkr., vents, & guns. Nabors #27-E° (0-13-0) Drlg. Foreman - S. Brady Mud Wt.: 9.6 ppg ,~. '~'~ Visc.: 42 Weather: Temperature: 16°/1° Wind: NE 13 knots Visibility: 15 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Mi]ne Pt. B No. 12 - CONFIDENTIAL (8,154' - Kuparuk River) AFE 10-61-1114 5-15 - PU guns, vents, pkr. & PBR. TIH w/ 243 jts. of 3~" 9.2# L-80 tubing. TIH w/Otis E-line. Space out & Ind. tbg. Displace w/80 bbls. d~esel. Close annulus, open VCV & partially inflate pkr. w/2350 psi. Open up backside & complete pkr. set. Press. up tbg. to 2900#. Bleed off tbg. Test annulus. PU & shear out PBR. Lnd. & lock down hanger. Press np to 3800 psi to open BPV. Test bottom of pkr. to 3000 psi; test SSSV to 1000 psi. Test top of pkr. to 1500 psi. No leaks. ND BOP; NU tree & test to 5000 psi, SSSV open. RIO RELEASED @ 0430 hrs. Nabors #27-E o(0-14-0) Drlg. Foreman - S. Brady Weather: Temperature: 17°/8° Wind: NE 6 knots Visibility: 4 miles STATE OF ALASKA , ALASKr IL AND GAS CONSERVATION C-~vlMISSION W .L.L COMPL =TION OR RECOMPL ..TION REPCRT AHD LOG ~. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~-~ ABANDONED ~ SERVICE ~ 2. Nar.~e of Operator i 7. Permit Number CONOCO, INC. 85-80 3. Address 8. APl Number J 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21338 J 4. Location of well at surfaceI! 9. Unit or Lease Name I 765' FSL, 920' FWL, Section 18, T13N, RllE, U.M. I Milne Point Unit At Top Producing Interval 10. Well Number 2900' FSL, 715' FWL, Section 18, T13N, RllE, U.M. B No. 12 At Total Depth 11. Field and Pool 3016' FSL, 678' FWL, Section 18, T13N, RllE, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 59' KB ADL 47438 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. t 15. Water Depth, if offshore 16. No. of Completions 5/1/85 5/11/85I 5/15/85I N/A feet MSL , 17. Total Depth (MD~-TVD) 18. Plug Back Depth (MD+-FVO) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7964 ' (7340 ' ) 7834 ' (7229') YES .~ NO L~ 1807 feet MDI 1800 ' TVD 22. Type Electric or Other Logs Run DIL-CNL- SFL-LDT-GR-SP-Porosity-Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZEI CEMENTING RECORD ;AMOUNT PULLED 13-3/8" 48# H-40 0 120' 17-1/2"'100 cf Perm Cmt 9-5/8" 36# K-55 0 4822' 12-3/4" 424 bbls Cold Set II~ 59 bbls Class G 7" 26# L-SO i 0, 7920' 9-1/4" ~52 bbls Class G 24. Perforations open to Production (MD~TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7724'-7757' (7133'-7163') MKZ and MK2 3-1/2" 9.2# L-80 7699' 7640' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5" Hollow Carrier 22 gram 12 spf DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) J FJ°w Tubing Casing Pressure iCALCULATED [OIL'BBL J GAS'MCF WATER-BBL jOILGRAVITY-API (c°rr'Press. 24-HOUR RATE ~1 J , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE __ 29. NA OA OB NAME M. Kuparuk L. Kuparuk GEOLO.GIC MARKERS MEAS. DEPTH 3976 4248 4518 4678 4744 7724 7961 TRUE VERT. DEPTH 3948 4192 4418 4545 4597 7133 7337 30. FORMATiON-TESTS .- Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / INSTRUCTIONS General' This form is designed for sqbmitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 113, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Eastman Whipstock ~ PETF~I..4NE CC~,PAI~' (907) 349-4617 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 May 31, 1985 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen Please find attached two copies of the Gyro Mnlti-Shot survey run for Conoco Inc., on ~a~ B, Well No: 12 ~' This is to be considered a formal letter of transmittal. The data herein, is to considered strictly confidential. A copy of this letter is being sent to Conoao's represen- tatives, Mr M. Bradshaw and Mr S. Davies. Should you have any questions regarding this survey data, please refer all questions to CONOCO INC. i tr~ ical Coordinator D s Fechn cc: M. BRADSHAW S. DAVIES jUNl i Alask8 Oil & G~s Cons. C~mmission Anchorage Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide l Eastrnan A PETROLANE COMPANY REPORT of SUB-SURFACE D #REC Ti ONA £ SURVEY CONOCO, INC. COMPANY Pad B, Well Number: 12 WELL NAME Milne 'Point, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY DATE A0585G0258 SURVEY BY B JAHN ~,~u~-~o~ R E C E IV E D ~-~'~-~ J U N i '1 Alaska 0il & Gas Cons, Commission Anchorage OFFICE ~cho~age, A1aska ." \ , r ( .. ' - Eastma~~ (907)349-4617 --- Whipstock - P. O. Box 4-1970/Anchorage, Alaska 99509-1970 A FfTROLANE COMF¥WY Da te: May 31, 1985 Conoco, Inc. 3201 C. Street Suite 20J Anchorage, Alaska 99503 \'lÌe11 Number: Pad B, Well No: 12 Location: Milne Pt., North Slope, Alaska 'rype of Survey: Gyro Multi-Shot Da te: ll-MAY-85 Method of Computation: Radius of Curvature Surveyor: B JAHN :Job Number: A0585G0258 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are ~nclosing the original and one copy of the Gyro Multi- Shot survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 copy delivered to drilling for in-house. d i str.' ibu t ion. B. 9 copies noted r oil company representatives. C ~ 3 copies for E/\\7 p(~:rmanC'nt 'W(?ll file::;" We wish to take this opportunity to thank you for using Eastman Whipstock and look forward to being of service in the future~ ~]. i... '...- r/:-:.l',r ¿~1' lOI1 , )NF Dis.i Technical Coordinotor cc/file . " I A D. ~ C> ':' () .~~'.r:. l~\""r.-, r;", ..,,] "', ,. !.. -' . C") cc: .J.. '. ~.ng,--.::>- .¡,.~s <\.hC JJX.l:' :"raclor: .,OLOCO O.G. Klel - P.E.S. ReservoIr SectIon Conoco B.E.. Gilliland ..- P.lLD. Hescfvoir ~)E:'cti()n Cc)noco William Van 1\ n -Alaßka 011 and (;,;18 r....~ons<2rvat:ion Commissi.on J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S~A., Inc. Concord Office Dale Bossert - Champlin Petrolewn Co. . C E ('.'';¡ ~ 'r I', ~ -:-. ,:J.' ") ", ", 1" 1 [) .:. J.. :'~"~ J:" ~') ,', r ,J' L"Y .:'" r '. :/. ._leery 1 ur" _. \.CcluJ.!,:) (.".t(.~ -)d\..¡~~::> ..'t::. C o.e !.lIt >'"",,)" Neil Buttr:am - Citi~?;:.~:; S(~rvìce Oil and Gas Corp. Directional Drillers/Sub-Surtace Surveyors/ Instrument & Tool Rentals/Sales/Worldwide ~'-:ONOCO~ INC. PAD B~ WELL NO: 12 GMS dOB NO: AO585GO25:E: MILNE PT. ~ NORTH SLOPE~ AL. ASKA GM'S~ 0-7:~:00 MD~ '.BI_~RVEYOR: B ,JAHN~ DATE RUN: 1 i-HAY-:E:5 GYRO NO: 2'F~l/26',B, CAMERA NO: 077~ ?0 DEG A/U NO: 1.24~: F 0 R E'.E: i G H T: N :_~: 7:3 ('~ W v E.h.. F I C A L_ :::;: F r'~: T I Ct N C A L. C U L A T Fi D I N F:'I. A N E Ci F F::" R 0 P ii ::-:.: A L D i RECT ! r')H: l'q /_:-, '!.)E.:.':Ei. 4:':: M I N. W R A 'r) I I..! S O F' C U R V A T I_1 R E t'.I E']" H i:} D Eastman -~'~.~ C 0 r.,t o C 0 .., I N r-:. F'AD B., WELL NO: 12 r'.~MS MILNE F'T..., NORTH '.-];LOF'E-, A L A S K A (-:0 M F' UT A ]" I 0 N F' A G E N 0. 1 T I ME ]]ATE · -, · ,-! f- l 4: O..5: =....":' ':' -.- 4 - M A Y - ,: ..... MEASURED 1]RIFT DEF'TH ANGLE FEE]' D M TRUE DRIF'T COLtR'.:;E VERTICAL VERTICAL D I R E C T I ri N L E N G T hi D F-. 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(]) !. 5 N '7'? :::0CI. 0 0 0 4(])(]). 0 0 0 100. I 0 (:)0. C),."-) -. C). "2':7-.' ':.") 100. I J 0 C". 0 c, -,'-':~'. ' '2':~ (]:,W 10,:.':.', ,, ]. :2 C.', (':). ,:::, 0 --(':). 22 (") ! 00. :1:300. (':)(-) - 0. 16 0 ! C) (-). !. -4. 00.00 --(')..1. ,/_-, ?41.00 1041.00 114 !. (])0 1241. ()C) 1:341.00 150Q. ,.':) 15 S 48 160("),, (") 30 S 4! :l 7,.'2.', 0 ,,(') 45 S 57 18(])0. 0 4 !5 S ;I.:':: 1. ':}' C) :Q , 0 45 '.E; ,:1.4 .1. ,.1.-,.I. :l ,, 00 1 !:5,:'I. 1. ,:.]),.') :l ,'.":, 4. Q, '!i:' 1 '74 C) ':-':"::' 1 ::-'.-', 40,, '.'}' 7 2000, 0 :BO ','..i: 100. 0 15 22Q0 0 1 '":' 2:2:00. C) 15 2;~00. 0 0 S 4:.-:: N 74. S 2/.:, hl 72 0 1 'i? 4 A. '?'7 ']:';') x'~l. i') ,..-~ ,'.. ,.~_,_ ._ ~, ... ~_~ 2 ! 40, 'iF: 6 2240 · '.-) 6 2 :':', 40, 96 250,:":~. 0 1 :::;_ 26,:i)0. 0 45 27(i)(]:,. 1 0 280 (") I 1 2'~.? (") 0. 1 3 0 N 4.'._--: N 27 N 45 N !5:'-': N 5.4 244 0 ':" 25.'-'-~ 0. ':'/'. 26,1. 0. 'F' 5 ::::740. 2 :-]: 40. '? 0 4,, 3 ::-: S 5_. ,_,':'.....~ W 7 .28 S .=; .... ::: 20 W 0 . .:...":' =i :3.6:'2 S /_-,. :35 W 7. :31 S /_-,0 2(-) W ¢). 51 .,..'-".._"::'::'.. S-"/ . 2 F;... gt '-'/. ,_,.../- ":: S 71 4 .'=;_ W0 .37 1. 1 C) '.S ,:,'-'. 7:3 bi ::'.: .80 S 8:2 4:E: W 0. ~"-:'o.. (). :2::..3 N 10 ,, 6 ./::, W 10./:,6 N 88 1 *.'f W 0.25 , astman Whipstock A I~'T,r'~OI_ANE PAI3 B: WELL NO: i2 GM MILNE PT., NORTH SLOPE A L A S K A ,_lOB NO: C: 0 M P U T A T I 0 I'q F' A G E N 0. '--2 T I ME DATE 14: 0 5: '-.? 9 2 4 -M A Y -:5:5 TRUE MEASURED DRIFT DRIFT COUR'.---;E VERT!CAL VERT!CAL FiEF'TH ANGLE El I RECT I CIN LEr',IGTH, DEF'TH '.:'-~:ECT I ON FEE'I- ti M I-I Fl FEET FEET FEET '.--.; I_1 B S E A T V D FEET R E C T A N G U L A R C [_ 0 ::_; I_1 R E Dr-~GLEr_ C 0 0 R D I N A T E '._=; 1FtI:--;TANE:E D!RECTION 'SEVERI"i FEET FEET Si M I3G / 100F 4 0 ()0. .... .,:.'""..:, ]. !:-;_ N ";'.. (-). E ! c)_ c)_ . ..:, '::;/-, '? . 7 ::ii: '~:',:_ ]. 5 .4 2 4100, 2 5:3 C:, N 5 C) E 10('-), 4'.']) A, 0, :3 6 :,2:5 5 ,, 6 7 .'.':I. 2 C, () ,, :2 ::2: ,:":,I',1 6 C, E 1 ,:;:,,.'-) ,, 4. 15,:]:,. J,. !":!; 2 '!;' '.:;:', 6 6 4:3 0 () ,, :!:',,:';:, 4 5 N &, 0 E 10 (]), 4 ::2: :.?, 7 ,, 2 9:3 4 7' ,. 5 ,:]:, 4 4 (")(") 3 4 (*) r,..t 5 (".~ E 1 o o 4:3 21 7' :3 "::":;'::; :3:3 .. - . ......... · . ._~ .,- .... :~I C 0 N r-~ F-i Fi, i N C. F'AD 'F:-, WELL NCI: 12 GM NILNE PT, ~ NFZqRTH SLOPE, ALASKA I": r'-i i'4 I::' U'f'A ]" I 0 i',l ]'! ME DATF 14: C)'.5: '29 :::-:4-MAY-P,.~-''] F' A F:i E hlr'l. :'::: TRUE h'IEA'._:;UREI-~ 'r'iRIFT 'FtR IFT COUR:--;E VERTICAl._ VERTICAL. :E:UB'.:;EA R E C: T A N G IJ L A R C L n ::: U R E f'~OGLE DEF'TH ANGLE DI RECTIOI",I LElx. Ii3'TI'"-'I DEF'T!4 SECT 101".-I TV/~ C 0 0 R D i N A T E :3 f"~I::;TANCE DiREC-F I1.-.li",.i SEVERI FEE]- D P1 D h'i FEET FEE]' FEET FEET FEET FEE]- 6000. :31 :'3(z) N 10 (:) W /"..:, 100, :-_-: 1 :2:0 N 12 ('7 W 6,200, :2:1 0 N 11 0 W 6, 5:00. i::1 0 N 10 0 W /.:,4~.])c). :30 45 N 11 0 W 18.27 E 1 '2:-2', 4., 1. 5 N (1) 4'P E ' (:), .5:3 ',3,30 E 1 '7:::--:5, :2::]:.: N 0 2..: 1 E 1.04 '-.-' c).=, !.4 '! .-..,,:,z 14 IXl c) ~ W c) 72 11.4:':: W 1't-3A,83 I",I 0 27 W 0.52 · .-.,c: 7::: t~! J. -,':} f:: -" , :39 N (') q.:~!: t,,.l C). ~7 .,._.... ~, . _ · - :.' _ . 6500. ::::,:-) 45 N i:Z': 0 W /'-,6,(z) 0. :2:0:2:0 Iq 1:3 0 &,7 o0 .... :2.:(") 1 '"'- hi 1 F; (')_ W /-, :::: ;-~ (') '.:"--~ 45 N 1. = (') W 69('-)0. :3('-) :2',0 N 14 0 W I, i. (")4 ("), 50 0.90 7000, 3,:'-) :30 I',1 16 (z) W '71 ':")0. :2:(") 45 I',.! 17 0 W 7'2(:)(") ,, :Z..-:: 0 5:0 1"4 !. '7 0 W 7:3(") 0, ::"',0 .,':'1. 5 Ix! 18 C') W 7q.C, 0. :31 ,:} N 1 :'2: 0 1,4 123. 1 i W 1. ',!!i',:3:7-;. 4.q. !",i :':-': 4 !:5 W 1:3',.:.',. 4:2: W 1. '.:;: 3 :i::. 5/; 5 154.2 :!i!', N l ,.,v ,, :.' ,, '2:J. :!31 N 4 7."50C). :30 45 N 18 (1) W '7;::,00, :3,1-) :30 iq J. 7 0 W 77 (")0 ,, :3 ! 0 I',1 1 :E: () W 7:i.:.',,."-:,':'-:,, :"?,0:3o N ,t.:E: 0 W F:'R O,J E C T E II T 0 l)IR I I_ L E" R '" S ]" D 100. 6'il) 4 (), 55 2 (]):3 :I ./_-, !d:, :.:.!: :::-: 1.55 2025. ;'_--, 1 Iq 100., '7026,6, 0 2 (3 ::31 ,, d:. 465:'/", 7.6 (') 2 (z) 7 fl-, 19 N :I 0 ,[':,. '7 ! 12. fl; 4 2 ! :31 ,, :F: 7 7'i') .':7; ::.:',. 5 4 212: 2. '.:.:' 5 N 1 ,:} 0, 715",::', ,, 4 :E:2::_' 1. 8 2.0 ! '71 :::: 9 ,, 4 ::.3 2171 ,, Iff :..3 I",1 170, i4 W 2.' 0:32,.74 N 4- 4:.:.:: W 1:!'35.46, 14 ?C):::3'2..4,5 t',1 !::'; 7 W 20 0,, :!'--: :7:: W21 :':.:: 2, .,':t :7: 21A . ,_,._,/.":' W.21'"""'",::,.,::. :36 r,.I !=i_ 42 w 0.57 ,:'). 72. '79/-, 4 '"" ........... '-' =' . ..... :,O :_--:0 N 18 (') W lA4 7:3:3'.:.),,7'? 22A:3 b,.'-'l. 7:Zu:::C). 79 7-2'25C) 74. N 2"'42 .- .... F I Ix!A L Ii:L 0 S U Fi E -' D I R E C T I ri N: il I :E;'f' A N C E: N 6 DEI3S :3 IqlN::; 45 SEC:._:; W 2265:, 75 F E E"F Easlman / COPlOCO? INC. PAD B? WELL NO: 12 GM'~-] dOB ~!0: AO585G025:--', MILNE PT. ~ NORTH SLOPE~ ALASKA GM'.E; .., ,:-:,-7::':0,¢') MD ..... '.::;URVEYOR: B , iAHN DATE R1..IN: 1 1 -I'"lm'~ .... -,::.-"::' ...... G Y R 0 N 0: 2'? 1 / 2,".-,8 .:, C A M E R A N r-'~: (') 7':.-':'., '? 0 El E G A / U t'.,.l 0: 1. 2 4 :E~ FORE:.--.;I GHT: N87 RECOR.EI 01:.':' ]: !"..FFERF'OI...ATE:':D ,.-;t. IRVE:'Y A F~TRO~.ANE C~k~PAJ'v~ ~ CONOCO~ INC. F:AI3 B~ WELL NO: 12 GMS MILNE PT. ~ NORTH SLOPE~ MEASURED DEF'TH FEET 100.00 200.00 :B 00.00 400.00 5 00.00 1100. C) 0 1200.00 ! :300.00 1400.0 C, 1500.0 ,~::, 2600.04 2700.0 !5 2:300.07 2900. 10 3000. 14 A L A S K A TRUE VERTI CAL_ DEPTH FEET 6 (1}0.0 C, 700.00 :_::00.00 'F' 0 C,. O,:Z:, 1 C, 0 c). C,,:') i 1 ("~0.00 1200.00 1:300.00 1400.0 C, . 1500.0 0 :;.' 1 (-~ 0.0 C) 2 ;.2 (I], 0,, () 0 :-2:30 (). 00 240 C,. 00 ~._, L)(.). 0 0 2600.00 2700.00 s/800.00 2900.00 3000.00 ,_10 B FI ID '- ::_; U B '.:; E A VERT I CAL. DEPTH F:' E E'I- 41.00 141. (i)0 24-1.00 :B41 . 0,:") 4 4 i. 0 0 54 i.. 00 A 4 !. 00 74. 1.00 841 ,, 00 941 ,, 00 1041. (3,:1) 1 ! 4. 1 1:24. 1 ,, 0 1 :_34:1 . 0 144 i. 0 C, i 54.1. ,, 00 1641.00 174. I. 00 .L 841 ,, 00 19-1 :L ,, 0 () 20 4-1.0 C) '~']. 41 2'..-'t 41 ,, 00 234. :L, (1) 0 2.4- 41.0 ~'-:, :2541.00 ::-]'.64.1.00 274 ] . 00 2841 ,. 00 294 i. 00 A 05:7-.: 5 G 025:3 R E C 'T A N G I_t L A R C 0 0 R Fi ! N A T F ::; FEET 0.00 0.00 0. o 0 0,. 00 c:,. 12 ::; c). 1:3 E (.-) .... , _,=- . . · z.._, '.B c) :3,'!., E (".', '".:'.'=; :--;o :.3' E :3.62 F-; 6. :'::5 W · -.":' :'::'?.. S /..,.:._, IAI 1.. 10. '.E; ,:,~'. 7:i: W 0.:3:3 N 1. 0.66 W 1.87 N 1:3.04 W C 0 M F' U T A T I El I',1 T ! ME DA-f'E 14:18:57 24 .... MAY-:B5 F'A G E ixlO. C L 0 '.:_; U R E f"~ I S T A N ti: E D I R E Ii: T I 0 N F E E'F D M 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.00 0 0 0.22 S 55 0 E (').. ,$:2: ':'._, '=~-, '-, O. EZ 0.4:7: S .~:;!!:; 0 .Fi i ,. C, 4- S 4. i '3.=]', tJ .,:.":' ,..'t. 2 S .q-Fi_ 22 t..,..t :::',. 4-3 '.E;4.7 :.:.:', W 4 m 73 :.E;4/:, 8 5 ,. 8';:t S 4.5 :_--:',.:_", W 6,:3:'3 :---: 48 21 W 6.76, S .4'.:.:' :2:':: W 7,14 '.E; .:,.:, 21 W 7,26 S 5i 4.:--: W '7 2:_:: :'-'; -'="-' :::o t.,J ..I .~, 7,, 31 S 60 2(1) W 7.6:3 S 71 4.5 W :--:. 80 ::: :::::2 4'F..' W 10,6,6 N 8:E: .1.5 W i:B, 17 N :3i -4-9 W Eastman Whipstock t, ) } A F~'TROt. ANE COg. fPANY .* CnhlCICCl, INC. F'AD B, WELL Nlll: 12 GM MILNE PT., NORTH SLOPE ME A'.--;URE'F~ DEF']-H FEET :--: 1 C) 0.2 4 :':: 2 0 (] ='-' :32=a} 1. 19 :--:402.54 3504.88 4.14:2:. 8222 · 4-2='-~ 21 .._1/ 1 45:: 7 4-. 2 6, 4 4 9 6,, C)0 4 6 21. 1. 5:2:55.03 5471.58 · _,._:,:..:,. 48 5706,. C:,0 ~ c,..],.=, :=: ~ 5 9 4 0.3:2: /=,C)57.52S' 6,174./=,6, 6:291.39 6407.90 ALASKA TRLiE VERT I C:AI... DEF'TH FEET ':' 1 c-)(-) c-)(') :--',200.00 :2: :2:0 0. (2)0 3:4.00. c-)0 · =,.., (2 (.). 0 :2: 6, 0 0.0 (2) :':: 7 0 0.0 C) :22 8 0 0. () :3 9 0,3.0 (2) 4000.0 0 4100.0 0 4'2 0 C,. C) () 4:2:0 C). 0 0 4 4 0 0.0 0 4 5 0 0.0 0 46,00.00 4700.00 4,800.00 4.900,00 50(_')0.00 510 C). 0 c) 52C) 0.0 c) ?] ::: 0 C). c':) 0 54C)C). 00 5500.00 5 6 0 0.0 0 5'70 O. 0 C) 5 8 0 0.0 5'P 0 0.0 0 6,000.00 ._lOB NO: SI_IBt=;EA VERT I CA1.. DEPTH FEET :}:(i)41.00 :2: ! 41.00 :3241. C)C) :=::34 1 ,, 00 3441.00 :3 6, 4 1.0 ,:") :3 7 4 1.0 0 ::::'3 4 t. (2) 0 :352' 4 ] . 0 0 4 0 4 1 ,, c'-:, 0 4 1,4:1. ,, ,:".'. 0 4-2 4 1,0,:.") 4 ::24 1 ,, ()0 4 4 4 1 ,, 0 0 4 5 4. 1. (';)0 4- 6 4 1.0 .,, / 4 !, c':)0 4 E: 4 1 ,, '.'-) · 4'=72 4 1 ,, 0 0 5 0 4 i. 00 5 24.1.0 0 5:2: 4.1.. 0 c) · ,544 1 ,, 00 5 5 41.0 0 5 6 41.0 c2) 5 74. _1 . 0 0 5 84.1 ,, C)0 594 1 ,, 0,::) R E C T A N G U L A R I:: l_-I I:1 R t-I I N A T E S FEET 5. 16, tq 15.78 W !2.2222 N 17.8272 W 2:2:. ,'."', 5 N 1 '?. 4 0 W 4 0.0 5 N 1 I~) i 'T; 5 W ,'.'=,1.75 N 19.74 W 8:ii:. c'-)t:, N 1222.9'P W I 1 '7. 2222 r,.I 1 7 ~ :'::'P w 1 5,:'.'). 2222 N 1 5. c")4 W 187 ''-lq 'I 1 '-"--W . O.'Z, .. . . ,:;, ._1 225.?. 4 :.=.': N 7.4-Y W 952. '.54 lq 64.4.6 E 1 0 1 2.22:4. N 62.52'22 E 107'2.60 hi 56.97 E ! 1 :_'_5-:222.5 2 N 4 7.0 6 E 119. :=:. 8 ("). N ."":.._,'::. :34 E 12 521222 =' ' ' .... ::,o N '-"-' '=:=' E ...' .=, ,, ...... 123123.55 N 12.523 E 1:37:2:. 26 N O. 5::-: E !4:32.42 N 1(').62 W 14 9 t.. '.':-' (") N 2 J. . 1-_, ~..':' W C 0 M F' I_l'f' A"F I 0 N T I P'IF{ DATE 1 4: 1:3: .5 }-' 2. 4-M A Y - :._=: 5 F'AC;E hlO. C: t Fi r.-:': U R E D t S T A N iF_.: E D i R E r£: T I Iii I',,I FEET ,'F~ M 16. E, 1 N 7 i :='1.'-'I- W :.7!.67 N Fi.=, 2:i. W :=',0,5'F; Iq :'::'F.' ::..':22 44.75 N 26, '::.".:;' W /,4 '-"-' N 1'7 44 'PO.("):2: N 12 10 W 1 i :3. ,'.'S 1 Iq E: :E:/i-, W 150.5):F.: hi 5 42}.': W 1. :=:::'--'::. ,:}5.7: N :2:37 t4 2 2'.=.;.6,0 N ]. 52 W '.;:'54. '7 2 N :7-: 5:.'::.,..: Iii..'. 1 (']) ! 4.2'7 N :3 :_.:22 E :[(_')'74. '1.1 Iq :2; :2 ii..-..; 1 12224.5c':) Iq '::2 2 :=', E 1 19 4-, 2222 1'4 1. 4. 2 E 1 '=':;":' 7 3 N 1 & E 1:'-':13, 6,1 N (:) :}]:3 E7 1 S: 7:2:. 2,..,/- N C) .! E 1 .,32222.4.6 N 0 26, W !4.S./1. :35 N 0 50 W ("-/--/Eastman A F~."FRO{ANE Cr3NOCO, INC. PAD B. WELL NO: I2 GMS MILNE F'T. , NORTH '.::LCIF'E~ MEA'.--;LiRED DEF'TH FEE]' '7,':, 8 !_'5.41 7:5:01.76 7'--~ t '7 ':'":' A L. A :::; K A TRUE VERT I CAL DEPTH FEET 6100. C) 0 6200.00 A 2 (')(z). (]) 0 6400.00 6500, 00 66 C: 0.0 (") /:,'700. (') 0 6 ::::: 00.00 6'F.' 0 o. 0 0 7 (:~(:) 0.0 0 7100. (")0 72 (")0.00 7 ::.: 00.00 ,_1F-t B I'q 0: SI_IBSEA VERT I CAI. DEF'TH FEET Z, 041.00 /'-, 14 '.1.. 00 6, :7:41.00 A:'::41.0 C) ,'344 !. 00 6541.00 6,"--, 41. C)0 6741.00 ,./:,',::: 41.00 7041.00 714 !. 00 '724- i ,, ,.'".~ 0 R E i_-: T A N G U L A R C n ~-~ R £1 i N A T E :_:; FEET 154'.-.-.,'. 2 :--: N 34. 19 W 1606.6:_:: N 47.:--:1 W 1/-. 63.01 l'q /--. 2. :.:.:.=, W 1719.0:3 1',1 77.04 W i-'-"- 75 . / :'.:,. N '?2. i I W 1C::::2.52 N 108,,77 W :[:389. 10 N 126. 16 I.,.! 19/4.~-3.6 ::-': I',I 144. 17 W '.-.' F) C) '.7' r...-,-:- -- ......... . ....... I',1 1 ~, 2.6 h W ';:' 059. t '7 N 1 :-3(2). 7:2 W 2115.::.:4 N 1'?:3..59 W 2 .t. 72.). 4. 2:: N 2 i 6. '.:.'-' :1 W :22'7::.B, 4. 5 t',l ,.-..:'-'"" ..... = I 1 W C~'zI h l P U T A ]- i 0 Ixl T I file DATE " "-z ' Ir"' 1-4: J. ::-:: % 7 ..:. ~-M q Y-,: .... C: L 0 F; I_1 R E D I :E; T A N C E D I R E C T I 0 itl F E E T D M 1549.66 N 1 16 W 1607.:B9 N 1 42 W 1664 1 :--: N '--''::, gl 1720.76 N 2 ,_-':4 W 177::-':. 14 N 2 !5 :--: W 18:B5.74- N :5:24 W .1. :::'.-:):3. :':: 1 N :3 4'? W 19.=i 1. 1.'.'1 :~-:: ~'\~ 4. i 4 20()'ii), !5 N 4:2:9 W 2067 ,, O'il;' N .5 ]. W F'A G E N r3. CONOCO~. INC. F'A.i].) B: WELL NO: 12 GMS dOB NO: AO585GC',25 MILNE PT. ~ NORTH :qLOPE~ ALASKA GMS~ 0-7800 MD~ SURVEYOR: B dAHN~ DATE RLIN: 11-MAY-85 GYRO NO: 291/2,':,::::, CAMERA NO: 077: '70 DEG A/U NO: 124 FORE'.E;IGHT: N87 3 OW R F:' C ("I R D O F: 1' t',.! T El R F:' r-~ L. A T [':' D '.--:; U R V E Y Eastman A/:~'rRO~ANE F': F~ N 0 r": r'.): I N C. PAD B, WELL Nr/: 12 GHS MI LNE F'T, , NARTH '.E;I...FIF'E, HARKER CODE NAME; ,_IA KA KB KC LA LB MA MB rqA NB NC ND hiE NF OA OB FiE LOWER CRET'. M KR 15:' T / I-.'.'. U F' I N T ,,. T / M K- ! B/MK-2 L T / L K- 1 DR I LLER'" S TD IJNCOt'qF. A L A S K A M E A S t..I R E D '["iE F'T FI FEET 3:917.00 :2:'P 7/:,. 00 :B 985. C) 0 40 :':-.: 2.0 (":, 4 ]. C, 5, ,:]:, 4127.00 417'7 ,, 00 4248. ':) C) 4 :B 31.00 4._, 1. 8. (":,0 4- 54 :.3.00 4.567.00 4582.00 4-/-, 05,. c:,,:") 4 6,56. ,:"; 0 4/':, 78.0 474. 4- ,, 00 4867. ,:'.)0 7 :B 74.0 7459.00 / ..:, / ~:,. () 0 7724.00 7769.00 7861.00 796.1.00 .J 0 B N 0: TRUE VI-':.-R T ! F:AL DEF']-H F-'!ZF.':T :':: 955. E', :39 '?',3.9 40 6, 5. :2~ :.3 40 ::', ":1. ,. 5:' 7 /I-! 2 9.6, 2 4. ! 5' i. 9 42.6:::. 47 44 :t. '7 /-. 1- 4545. 14 4. 597 ,, :.38 46,':.? 4. ,, (-31 6, E', i:: 2.4. 0 6705. :36 7005.09 71 :'::::3. 17 7171.84 7251.04 7337.20 '7:3:3 ?. 79 '.E;L1B:Z;EA r'-' ~ V,--- R T I CAI. DEF'TH FEET :3888. == :389 6,. 89 :B9:37. 4.006, 3:B 40..-: .:,. ':T., 7 4,:')7,:-~ 4.15:2.5) 8 4- 204.4'7 4358.66 4378. ¢;-. 6 4397. ::36 44 O'il). F.i/-.:. 4428.2 ::;' 44. 6,',F:. 6, 8 6, 946, 09 7074. 17 7112. E:4 7192.04 7278.20 7280. '79 r': A I¥! F'I..i ]" A T I 0 N T I ME DATE 14: lO: ?;1 ..... -'=' ..... -' 4-MA ~' -,: .... F'AGE NO. R E C T A N G U L A R C 0 CI R D ! N A T E S FEET 184,,78 N 12. 15 W 2c) 6.87 N 'P.8:B W 210.24 N 9.4.7 W 22:3. '--'.. ':,.. N '7. ._,= C) W ._,-., 14 N 4 :--:.=; W 269.00 r-,I :Z-:. 40 W 291.4.0 N 1.25 W :32:5. 11 iXl 2.2.1 E :Z-:6,7.0C) N 6.4 6, E 472 :1.8 I',1 .t.,:,. ! 8 E 4.87..1.0 N 17.75 E !:";ot 42 txl 19 .... '~'= _ .. # # .,.~.._.1 ~]_" '"'-]'.lC)._ . ,, ::',7 hi 2,:-) , 1'"'... E 524-. 1 :':: iq ':;: 1,/'::,'? E 554.95 N '7.:'.5., 48 E 5,'58 ,, ';.::' 4 N 27. 11 E 6.':':)8,. 27 N :B 2. C)2 E E, 8 2. '0 2 N 4- 0. ',::i: :2 iF_:: 196,4.11 N 150. 16, W 2 (305. ,,/:, 0 N 16,:3. ,<':. 4 W 206,2,04 N 181,6:'-:: W .,.' 1:34 ../:',. 2 lq204 . ....._./. ":' 1.4 2::1.56.50 N 21.!.74 W 22C)1,(')2 N 226,:;:'0 W 2249.29 N 241.88 W C L 0 '.3 U R E D I :E:TANCE D I REC:T I ON F E E -i~ D I'fl 1 :::_ ffi_. 1 L:: N ._,":' 46, W :207. :ll N :2 4:3 W 71 (3 4/-, N "/-" '-'= W ~ . · .. ."t,_l 229. 12 lq 1 5:2: W .--, ~-- 1-~ · .' .... :-.. 18 N 0 58 W '.-'. ' 69. ~"-)2 N '.']) . W '":":'1.4.0 N 0 15 W 32 ._, 12 iq 0 2:B E 3/.37.0,'_":, N 1 1. E 4-'72.4;"., N .1. 58 E 48'7.42 N 2 5 E !501.'75) lq 2 12 E 5 i ,::::, ,, '77 N 2 16, E '=" '-' Z!. ,, t:= ,-, ._, .-' . ,.: 1"4 2 22: E: = r.:.. =- .r.=i :::: _, ...... , ..... I'..t 2 :B8 E 5 6 ::-'i:. 89 N ::.;.' 4. 4. E /_:.'::Y::). 11 Pt :2: 1 E 19/_-, 9. :.':': 4N 4. 22 W 2O 12.26 N 4 /:' '4 2:0'70.0 :.:.: N 5 2: W 21. 4. 4.41 iq !:-'; 29 W 2:1.6,6.87 N 5 36, W '")'":'12 / '-' N '%] ="-' · '.4. ,. 0.4:. .- ..[ .~.2 W 2262 2A N 6 ':' W 2:26:'::. 75 N 6 9 W /-/"7 Eastman - Whipstock l A t~'TROLANE CO~PA2VY CONOCO, INCo PAD 'B, WELL NO, 12 GHS HILNE PT,, NORTH SLOPE, EASTHAN WHIPSTOCK, INC. ALASKA HORIZONTAL PROJECTION SCALE ! IN. = 500 FEET DEPTH INDICATORs TVD ........ · ..... ~sst 1 FINAL STATION, DEPTH 7'964 I'ID.. 7339.79 TVD NORTH 2250.7'4 WEST 24.2.35 -- CLOSURE-2263.7-5 N 6 8 4.5 W ~6 79.. · 5224. ! \ 4800 I ' CON 0-C6'*;-' ! Nc, ' ~ PAD .B, -I/ELL NO~ 12 G~S '._'_M.I.LNE .PT..' NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK, INC. 5OO ....... 2000 · i ' ........ 4000 ~000 1500 2500 , 3;500 5500 "~~500 '% .7500 V ERT:~"C-AL. PROJECTION, SCALE 1 IN~ =}2000 FEET ' 4000 i. i! 0 2000 : ! VERTICAL SECTION ..... i,,,.,:.._~ .......... ! ............ ' ......... CLOSURE 2263.75 N 6. 8 45 W - ' Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report ~_ell Core Ch~ps Core DescrSpt~on ~~- ' Registered Survey Plat Inclination Survey S rv.y Digitized Data , L.FJ.04 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of ©~erator gonoco Inc. 3. Address 3201C Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well 765' FSL, 9201FWL, Sec. 18, T13N, R11E, U.M. 7. Permit No. 85~80' ' ' ' 8. APl Number 50_.029-21338 9. Unit or Lease Name Milne Point Unit 10. Well NumbeF B-12 1 1. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 59' KB I 47438 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing St im u late [] Abandon [] Stim ulation [] Aba ndonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as a water injection well on 11-30-85, and its status should be changed from suspended to service and classified as a water injection well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"') ~/¢2-~- /] - ~<¢--~ ~/~'~-'-~--- Title ~ ,./~ ¢"--¢~-~/%, .~ Thin'ce b~for Commission use Conditions ~f Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate conoco John R. Kemp Manager of Alaskan Operalions Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 October 11, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No.·CFP-1, CFP-2, B-5A, B-6, B-7, B-8, B-9, B-lO, B-il, B-12, B-13, B-14, B-15, and B-16. If you require additional information concerning these completion forms, please contact Jim Hand at 564-7640. Very truly yours, (~~anager of Alaska Operations lb RECEIVED Alaska Oil & Gas Cons. Commisslo. Anchorage STATE OF ALASKA0 I{ 16 t A iL ALASKA.~ ..... AND GAS CONSERVATION O. _..~,VIlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~: ABANDONED [] SERVICE ~ 2. Nar,~e of Operator 7. Permit Number CONOCO, INC. 85-80 3. Address I 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 I 50-029-21338 9. Unit or Lease Name Milne Point Unit 10. Well Number 4. Location of well at surface 765' FSL, 920' FWL, Section 18, T13N, RZ1E, U.M. At Top Producing Interval 2900' FSL, 715' FWL, Section 18, T13N, RllE, U.M. At Total Depth 3016' FSL, 678' FWL, Section 18, TZ3N, RZ1E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 59' KB I ADL 47438 12. Date Spudded 5/1/85 17. Total Depth (MD+TVD) 19. L ~rectional Survey 7964 ' (7340 ' ) Yes ~ NO [] BNo. 12 1 1. Field and Pool Kuparuk River Field Kuparuk River 13. Date T.D. Reached 5/1~/85 18. Plug Back Depth (MD+TVD) 7834' (7229') 14 ..r-. te Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions I 5/15/85 N/A feet MSL I 1 20. Depth where SSSV set 21. Thickness of Permafrost 1807 feet MD 1800 ' TVD 22. Type Electric or Other Logs Run DIL-CNL-SFL-LDT-GR- SP-Porosity-Gyro 23. CASING SIZE 13-3/8" 9-5/8- 7" NT. PER FT. 48# 36# GRADE H-40 K-55 26# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 0 120' 17-1/2" 100 cf Perm Cmt 4822' 24. Perforations open to Production (MD+TVD of Top and interval, size and number) 7724'-7757' 12-3/4" 0 7920 ' 9-1/4" ]ottom and (7133'-7163') MK1 and MK2 5" Hollow Carrier 22 gram 12 spf / 424 bbls Cold Set II~ / 59 bbls Class G 52 bbls Class G 25. TUBING RECORD SIZE I DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.2# L-80 7699' 7640' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. Date First Production Date of Test Hours Tested PRODUCTION TEST Flow Tubing Casing Pressure Press. 28. CORE DATA IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FORIOIL-BBL GAS-MCF TEST PERIOD I~ CALCULATED O IL-BBL GAS-MCF 24-HOUR RATE WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL IOILGRAVITY-API. (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' ..... 30. . . · . GEOLOGIC MARKERS ' ' FORMATION TEsTs . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 3976 3948 MA 4248 4192 NA 4518 4418 OA 4678 4545 OB 4744 4597 M. Kuparuk 7724 7133 L. Kuparuk 7961 7337 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ,~¢~, ~._~~ Title EnQineer Date ]0-22-85 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 GEARHART'INDUSTRIES, INC. " CUSTOMER c[~oco, FIELD KL~ARUK ' J~ NORTH SLOPE ALASKA We]] Name lV[[I~ I~Z)IbTE UNITL~-J'2 County State Type of Logs Distributed(~BLle~%RC~L~,i-)%L_, ~[ Date Date Job Ran~-~G.~q_ ~ Blue Line. .~. Sepia Pre-Fold ~ Rolled Logs mailed to' COMPANY PERSON ADDRESS ALAS~ OIL AND GAS W]]LLItt~/vI 'VAJq' ~T,T,FIN' ~.))-L,.. 3001 PORCUPINE DRIVE CRRRt PRINTS MAILED FROM DISTRIBUTED BY TESSIE HORNBEC~ 2"/100'./' TYPE 'TOP DEPTH \q~9, qR~O 0 B~O~OM DEPTH aq ~,q '1 qq:q ,-'.-,,) :'//l~: 5"/100' TYPE -1 q crt) bOcSb,- i dq0X · Please date and sign and return in the enclosed self-addressed and return to Conoco. NO. OF LIS TAPES SIGNED DATED RECEIVED oclO / 1985 Alaska Oil & Gas Co::~ ......... :ssion Anchorage 139 East 51st St., Suite 102 P.O. Box 102436 Anchorage, AK 99510 Te/ephone (907) 562-2538 G~zII?HA~ GEARHART INDUSTRIES, INC. CUSTOMER CDNOOD, INC, FIELD KUPARUK We]] Name lVIZI_~ POINT UNIT County I<UPARUK State ALASKA Type of Logs Distributed~\L ~ ~)L\C~ ~ C.~q~R:e~\e~s Date Job Ran S-~v-~q-~S Blue Line I Logs mailed to' Sepia Pre-Fold ~) Rolled PRINTS MAILED FROM GEARHART INDUSTRIES DISTRIBUTED BY TESSIE HORNBECK 2"/100' TYPE ~-~i ~ · 5"/100' TYPE DEPTH BOl-fOM DEPTH IP~--~ ~ Please date and sign and return in the enclosed self-addressed and return to Conoco. NO. OF LIS TAPES SIGNED DATED Gas Cons. Anchorage John R, Kemp Manager of Alaskan Operations Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 (907} 564-7600 September 27, 1985 Mr. Robert Burd, Director U.S .E.P.A. Water Division, Region X 12OO Sixth Avenue, M/S 409 Seattle, Washington 98101 Dear Mr. Burd: Attached please find completion reports for Milne Point Unit injection wells B-7, B-8, B-12 and C-12. Also included are wellbore diagrams and geophysical logs for the subject wells. All four wells were issued emergency permits in accordance with 40 CFR 144.34 (a) (3) on December 21, 1984. Completion reports for other permitted Milne Point wells will soon be submitted. Please call Rod Schulz at (907) 564-7600 if you have any questions. ~Y°urs very tr~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RECEIVED OCT o 1 185 Alaska 0il & 6as Cons. Commlssio. Anchorage &EPA ~ ~NII'ED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, DC 20460 ~ COMPLETION REPORT FOR BRINE DISPOSAL, HYDROCARBON STORAGE, OR ENHANCED RECOVERY WELL NAMEANDADDRESSOFEXISTJNGPERMI~EE Conoco Inc. 3201 "C" Street Suite 200 Anchorage, AK 99503 NAME AND ADDRESS ~F SURFAdE OWNER State of Alaska Form Aoprovad OM8 No. 2040-0042 -Approval exotres ~-JO-R6 LOCATE WELL AND OUTLINE UNIT ON SECTION PLAT -- 640 ACRES W --! ~ J.- 4- I I I I I I _J I l, _1 ! 1 I i I I I I J I i" I 1 I I I I i I STATE COUNTY J PERMIT NUMBER AK North Slope Borough I AK-2ROO75 SURFACE LOCATION DESCRIPTION NE ,A OF SW ~A OF SW ~/i SECTION ~8 TOWNSHIP 13N RANGE ] iF~ LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLING UNIT Surface LocaTion 7 6 5fl. from (N/S) S, . tine of quarter section and92._.~0 ft. fromtE/~ W lineofauartersection WELL ACTIVITY TYPE OF PERMIT F'~ Brine Disl~3sal D Individual Estimated Fracture Pressure r~ Enhanced Recovery r~ Area of Injection Zone [~] Hydrocarbon Storaqe Number of Wells ? ? . 7 5 p s i / f t. A.ticipated Dally Injection Volume (Bbls) Iniection Interval Average j Maximum Feet io Feet 4000 10, OO0 7,724 7,757 AnTicioated Daily Injection Pressure IPSI) PeDth to Bottom of Lowermost Fresr~waTer Format,on Average Maximum (Feet} 19OO 2500 3100' (See UIC Permit) Type of Inlechon Fluid (Check the appropriate blockfs)) 'j Lease Namej, Well Number ~SaltWater [~ Brackish Water [~] Fresh Water I Milne Point Unit ] B-12 r-] Liqu,d Hydrocarbon [-'] Other Name of Injection Zone Kuparuk River Date Drdling Began J Date Well Comoleted Permeability of Injection Zone May 2, 1985 J May 15, 1985 ~ 60- 3OOmd Date Ordhng ComDleted j Porosity of Injection Zone May 11, 1985 I 20% CASING AND TUBING CEMENT HOLE OD Size VV~/Ft -- Grade -- New or Used Deoth Sacks Class Depth BiT Diameter 13 3/8" 48#-H 40 - New 120' To Surface + 140' 9 5/8" ;, 3 1/2" ' 36#-K 55 - New 26#-L 80 - New 19.2#-L 80 - New 4822' , 79~0' 7640' 1240 285 , 255 ,%rctic Grade ]old Set II% G .4.~865' 7,964' 17 1/2'.' !12 1/4" 8 1/2" INJECTION ZONE STIMULA~ON WIRE LINE LOGS UST ~CH TYPE , . Int~mel Treat~ MeTe.als end Amount Used Loq Types L~ged laterals DIL- SFL - OR 7962 -4820 CNS -CDL - CAL 7944 -7500 CNL in csg 4914 -1982 _Comolete Attachments A -- E listed on the reverse. CERTIFICATION I cern'fy under the penalty of law that i have personally examined and am familiar submitted in this document and afl a~achments and th t, based on my inquiry of tho~e i.5~ivigubT~ immediately respnnsible for obtaining the information, I believe that the information is.t~ue, ~accu~ate, and complete. I am a ware that there are significant penalties for submitting false informbtioh, the possibility off/ne and imprisonment. [Re(. 40 CFR 144.32). g~a~k~ NAME AND OFFIC~L ~TLE ~leese ~ or p,tnt) John R. Kemp Manager of Alaskan Operations EPAForm ~520-10(2-~4) B -12 ATTACHMENTS A See attached diagrams. B Pressure tested 9 5/8" casing to 1500 psi for 30 minutes with 150 psi bleed-off (within regulatory requirements.) Applied 2900 psi to the tubing to set the packer. Pressure tested the inside of the tubing to 3000 psi for 10 minutes with no bleed-off. Pressure tested casing- tubing annulus to 1500 psi for 10 minutes with no bleed-off. Pressure tested tree to 5000 psi for 10 minutes with no bleed-off. C A report was submitted on May 15, 1985, which was approved on June 21, 1985. D No defective wells. E Included are final prints of the DIL-SFL-GR and CNS-CDL-CAL logs. GEARHART INDUSTRIES, INC. CUSTOMER CONOCO, TNt_ FIELD ~OPARU~ Wel 1 Name MII_NE POINT UNIT_~-lO-County NORTH SLOPE State ALASKA lype.of Logs Distributed C%~/~, . \. Oj~b% Date Job Ran ~-\\ - cE~ Blue Line \ Date (~_ ~- ~ Sepia Pre-Fold J Rolled Logs mailed to: COMPANY PERSON ALASKA OIL AbTD ~ WILLIAM VAN AT,T:F~ ADDRESS 3001 PORCUPINE DRIVE CRRR~ PRINTS MAILED FROM DISTRIBUTED BY GEARHART INDUSTRIES TESSIE HORN-BECK 2"/100' '[DP DEPTH BOTTOM DEPTH TYPE 5"/100' TYPE Please date and sign and return in the enclosed self-addressed and return.to~. Conoco. NO. OF LIS TAPES ~ SIGNED DATED ( / AlasKa Gone, Anchorage 139 East 51st St., Suite 102 P.O Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 Conoco Inc. 32Ol c Street Suite 200 Anchorage, AK 99503 June 6, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Monthly Report of Drilling and Workover Operations Attached for your information and file are the original and one copy of each of the required Monthly Reports of Drilling and Workover Operations conducted during May 1985. If you should have any questions, please call Lynn Alexander at 564-7609. Very truly yours, J R Kemp ~ ~~laskan Operations LA/ab Att. R CEtVE Alaska Oi! & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO"MISSION MONTHLY REPORT_ ,= DRILLING AND WOR. OVER OP--.RATIONS 11. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 85-80 3. Address 3201 C Street, Suite 200, Anchorage, AK 99503 4. Location of Well at surface 765' FSL, 920' FWL, Section 18 T13N, RilE, U.M. I 6. Lease Designation and Serial No. ADL 47438 8. APl Number 5o-029-21338 For the Month of. May 5. Elevation in feet (i-dm-ate KB, DF, e[c.) 59 'KB 9. Unit or Lease Name Milne Point Unit 10. Well No. R Nh. 12 11. Field and Pool Kuparuk River Field Kuparuk River · 19 85 : 12. Del~th at e~d of monzh, footag~ drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date: 5-1-85. Wireline pulled out of rope socket w/35OO# line pull @7700'. POOH w/wireline. PU double bowl overshot w/grapple to catch 2-5/16" fishing neck & 3-1/2" tool body. Tag fish @7740'. Retrieve fish. Drilled from surface to 7964' this month. Depth at end of month: 7964'. 13. Ca~J~j o~ ~ir~ run an~ quanzitJes or c.~ment, results of pressure tests Ran 122 jts. of 36#/ft K-55 9 5/8" Butt. csg. Set w/424 bbls. of 12.3 ppg. Cold set Ill w/4 lb/sk gilsonite, followed w/59 bbls. of 15.8 ppg Class "G" w/3% NaC1 & 0.2% D-6. Cement returned to surface. Ran 200 its of 7" 26# L-80 csg. w/butt, threads. Pump 52 bbls. 15.8ppg Class "G" w/0.8% D-19, 0.25% R-5, and 0.1% D-6. Full returns. 14. Cori~cj res=J"ne ar~ brief de-,cr, iption None 15. Lc,~_ run a~ d~[h wh~e run DIL-CNL-SFL-LDT-GR to 7745' GR, DIL, & SP from 7962' to 4820'. CNL & GR from 4822' to 200'. Gyro and Gamma ray run. Porosity logs from 7962' to 7500'. 1 6. DST data. p~rforat~cJ da~a, shows of H2S, rmsceJJaneou$ data None 17. I hereby cert,fy that the foregoing is true and correct to the best of my knowledge. NOTE -Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7.1-80 ADDITIONAL TAPES TO: = * CITIES SERVICE: BAKERSFIELD, CA READING & BATES:TULSA,OK CHAMPLIN: ENGLEW00D, CO CHEVRON USA:ANCHORAGE SCHLUMBERGER OFFSHORE SERVICES ALASKA OIL&GAS:ANCHORAGE 500 W. INTERNATIONAL AIRPORT ROAD CONOCO :ANCHORAGE ANCHORAGE, ALASKA 99502 CONOCO :PONCACOMPANY CITY, O~~~ . L OCATION ' ,~~'~//-~-/'~.~/,~,/'~/~ N_o 000245' v/'C6~UTING CENTER PRINT CENTER WELL NAME ' //ff//~- ~//~ WELL NAME ' SERVICES ' /'-'~//~/J SERVICES ' NO. OF BOXES' JOB NO. ' ~~~ JOB NO. ' ADD'L TAPES ' NO. OF BOXES' ADD'L TAPES ' WELL NAME ' /~/~C-/,=.~ WELL NAME SERVICES ' /---~/p/z//g/~ SERVICES NO. OF BOXES' JOB NO. ' ADD'L TAPES ' NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · WELL NAME SERVICES · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES ' NO. OF BOXES: .~?Ff~/-.- JOB N0. : /& ~ .'--~_~ ADD'L TAPES ~a~l~ On o . ~ o ~~~ -' ~ ~as ~o~ ~'~ SCHLUMBERGER COURIER DATE DELIVERED RECEIVED BY . _.. GEARHART INDUSTRIES, INC. CUSTOMER CONOCO FIELD KU~ARUK RIVER Well Name M!LNE POINT B -]? Type of Logs Distributed '0 ~ County NORTH SLOPE State ALASKA Date JUNF, 6, ]985 Date Job Ran 5-1~]-85 Blue Line ~ Sepia Pre-Fold rk Rolled Logs mailed to' COMPANY PERSON ADDRESS CRRR# ALASKA OIL AND GAS WTIITAM VAN ALEN 3001 PORCUPINE DRIVE PRINTS MAILED FROM DISTRIBUTED BY GEARHART INDUSTRIES TESSIE HORNBECK 2"/100' TOP DEPTH BOI-rOM DEPTH TYPE CDL/CNS r~ ~ (3'D ~C~ ~ 5I,/loo' TYPE CDI /CNg CDL/CNS Please date and sign and return in the enclosed self-addressed and return to co.oco. NO. OF LIS TAPES (,_. ' -~_ SIGNED ~r,,,///. ~./~J/_ i'" ~ -~'~~. ' _~. ~'~'? : Alaska Oil & Gas Cons, Commission Anchorage 139 East 51st St., Su/te 102 P.O Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 MEMORANOUM State-of Alaska ALASKA OIL AND GAS CONSERVATION CO~R~ISSION TO: Co Vo ~~e~ton Cb_a ir~a~/%-~ : .. THRU: Lonnie C. Smith ?' ~' (~ Commis s ioner DATE: FILE NO: TELEPHONE NO: May 13, 1985 D. EWS. 37 FROM: Edgar W. Sipple, Jr~~ Petroleum Inspector,S../-~' SU BJ ECT: Witness BOPE Test on Conoco's ~filne Point B-1° Sec. 18, T13N,RllE,L~, Permit No. 85-80, Nabors Rig 27E. ~ond_a~~~ 6, 1985: I traveled this date from ARCO's Kuparuk L-l---l] (subject of Jnother report) to Conoco's Milne Point B-!2, Nabors Rig 27E, to witness a BOPE test. The drilling contractor vzas i~_ the process of nippling up. The BOPE test commenced at 6:00 am and was concluded at 8:30am. There were no failures. i filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on Conoco's Milne Point B-!2, Nabors Rig °7E Attachment 02.001AlP, or. 10'791 STATE OF ALASKA ALASKA oIL & GAS CONSERVATION- COM14IS.~ION B.O,P.E2 Inspection Report Inspector /__~/~/~,~ ~ ~/jj~/~ ~',/~._ Well Operator~~ ~ ~ ~ Representative S~~ Location~,.Sec !Y TI~R~IE~X .~'Casing Set ~ V~ZZ ft. Drillins Contractor ~~ Rig #R~ Representative ~, /~ Location, General ~ Well Sign~ ACC~ATOR SYST~ General Housekeeping. ~ Rig ~ ~ Full Charge Pressure ~~~ ~psig Reserve Pit ~ ~ Pressure After Closure /~.~ Psig Mud Systems Visual Audio pUmp incr. clos. pres. 200 psig ~min~. sec. Trip Tank ~ ~ Full Charge Pressure Att~ed: / ~ mina~ sec, Monitor ast r Gas' Detectors ~ Remote~ Blinds switch c°ver~l~ ~~ O~~r~. C~ ~ ~ ,~~ ~'& Kelly and Floor Safety Valves ~' ~?.{~ BOPE SteeP/ Test Pressure Upper Kelly ~/Test Pressure ~~r Preventer ~ ~~ Lower Kelly~/ Test Pressure ~~'~ - " ~- ~k .~~ Ball Type ~ ~ Test Pressure Blind ~ ~ ~m~ Inside BOP ~ ~t Pressure C~~Line Valves~ ~ Choke Manifold ~k Test Pressure Kill L~e~alves ~ ~~ No. flanges ~f Check Valve ~D ~ ~A~ ~ Adjustable Chokes ~ ~ .~ Hvdrauically operated choke /--/~ Test Results: Failures Test Time Repair or Replacement of failed equipment to be made within ~/~days and Inspector/ / . Co~ission office notified. Remarks:~ . ~~ ~ ;~,~T,~ ~ ~ ~'O~ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~~ ~'. ~~JZ/' April 30, 1985 Mr. James R. Hand Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. B-12 Conoco Inc. Permit No. 85-80 Sur. Loc. 765'FS!,, 920'~YL, Sec. 18, T13N, RILE, UM. Btmhole Loc. 2085'FN!,, 4575'FEL, Sec. 18, T!3N, RILE, Dear Mr. Hand: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional suz-~ey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawm_ing or migration os anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. James R. Hand Mi!ne Point Unit B-12 -2- April 30, !985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment b~fore the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, / C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~.~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery John R. Kemp Manager of Alaskan Operations Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 April. 19, ].985 Mr. C. V. Chatterton, Chairman Alaska Oil. and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear ~-Ir. Chatterton: Enc].osed are the original and two copies of the Permit to Drill application for Milne Point B-12. A $].00 check is being submitted with the permit application to fulfil], the permitting fee requirement. If you have any questions, please call Jim Hand at 564-7640. Very tru].y yours, /,, . / i ~;r John R. Kemp Manager of Alaskan Operations JH/vv cc: MP B-12 Correpondence Fi]_e 6as Cons. Commission AnChorage STATE OF ALASKA ALASKA ._ .L AND GAS CONSERVATION CC. ,-MISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL {%] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL~ DEVELOPMENT GAS [] SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator Conoco Inc. 3. Address Alaska 0il & Gas Cons, ¢ .... --',, 3201 "C" Street, Suite 200, Anchorage, AK. 99503 4. Location of well at surface 765' FSL~ 920' FWL~ Sec 18~ TZ3N~ RllE~ U.M. At top of proposed producing interval 2300' FNL~ 4550'FEL~ Sec ]8, T13N~RllE~ O.M. At total depth 8~ - 2085' FNL~ 4575' FEL~ Sec 1 T13N~ RllE~ U.H. 5. Elevation in feet {indicate KS, DF etc.) I ~. Lease designation and serial no. KB 59~ Pad 24~ I ^BL 47438 12. Bond information {see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi NW of Deadhorse miles 634' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8,154' MD 7470'TVD fe~t 2~544 Anchorage 9. Unit or lease name Milne Point Unit 10. Well number B No. 12 11. Field and pool Kuparuk River Amount $200~000.00 15. Distance to nearest drilling or completed well B-8 201 feet 18. Approximate spud date 5/0i/85 3i00 psig@ 59 ~ ! 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures __ Surface KICK OFF POINT 3000 feet. MAXIMUM HOLE ANGLE 33° o~1 (see 20 AAC 25.035 (c) (2) 3700 psig@ ft. TD (TVD) 21 ' Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) Hol17~,,e 13 3/8" 48 H-40 PELP 80' 35' I 35' 115' I 115' ±100 cf Permafrost Cmt ]_2k" 9 5/8" 36 K-55 BTRS 4845' 35' I 35' 4880' I 4719' ±1240 sks Permafrost Cmt I I i I ±275 sks Class G 8~" 7" 26 L-80 BTRS 7954' 35' I 35' 8154' I 7470' ±255 sks Class G I I ±1~o s~s Fermafrost Cmt .... ;~ ........ ~ ....... . ±60 ~L Arctic ~a~ proposed program: Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River field. Mud system wil: be non-dispersed, low solids with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be ]0.2 ppg. A 20" 2000 psig diverter will be installed on the 13 3/8" conductor for drillin the surface hole. A 13 3/8" 5000 psig RSRRA BOPE stack will be used on surface casing. Pressure tests will be performed as per State Regulations. ~.~ximum anticipated surface pressure was based on a fluid column at T.D. of 80% gas and 20% oil. Casing will be pressure tested to 1500 psig. B No. 12 is no closer than 201' to B No. 8. t The B-12 well wJ. ll progress away from the B-8 well as it is drilled in a northwest direction. Arctic pak will b~ placed ~n the 7" X 9 5/8" annulus after disposing of test oil and exces~ drilling fluid. The perforating and | completion assemblies will be run ~n the well before releasing the drilling rig. The perforating guns will be detonated and the well flow tested once the drilling rig has moved off location. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~,~ / ~ TITLE Engineer DATE April 19~ 1985 The space~w for Commission use CONDITIONS OF APPROVAL Samples required ~YES Permit number APPROVED BY Form 10401 Rev. 7-~ -80 Mud log required I Directional Survey required APl number I--lYES [~O I j~[.YES •NO 50- O~ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE April 30, 1985 by order of the Commission Submit in triplicate SUPPLEHENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Hilne Point No. B-12 Conoco Inc. 3201 "C" Street, Ste 200 Anchorage, A].aska 99503 I. CEMENTING PROGRAM Ao The 13-3/8" conductor will. be set st 80' below the surface (115' K.Bo): then. cemented to the surface with permafrost cement. B~ The 9-5/8" surface casing will be cemented with ±1240 sacks of Permafrost cement followed by ±275 sacks of Class "G" cement. A top job will. be done if cement is not circulated to the surface. The 7" production casing wi].l be cemented in two stages. The first stage will_ consist of ±255 sacks of Class "G" cement pumped around the casing shoe (estimated ±1400' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'C' cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6600' subsea TVD. ]!I. FORb~TION EVALUATION A. W~.reline logs for both the 12~" hole (from casing point to ±2500') and for the 8~" hole (from T.D. to ±lO00'above the Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. iV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used. from 0'-1000'. V. A low solids non-dispersed gel/water mud system will be used from ]O00'-Surf. Csg. Pt. Low solids lightly dispersed mud system 4880'-T.D. DIRECTIONAL PROGRAM The B-12 well wi].], be drill.ed to a proposed KOP of 3000', then build angle ~.n a north 6.7° west direction. The c].osest that the B-12 will come to another wellbore is at the surface, where tbe proposed B-J2 will be 201' ~~of the existing B-8 we].]. An t~TD too] is to be run while drilling for surveying purposes. Final hole angle will be 32.8°. The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 300', a Sundry Notice wi]]. be submitted. Ar~chor~,~ ~--~LL J LOCA1.10N IN 5F_CI'ION ~ nO~ S L~NE fnOea w LiNE B-I2 8-PJ ~} .14 r5 -- ~6 464 790' 920' 300' ~tI.N! ~ UN~T IICI~,,IDARY SI.AT E PLANE CO-OhOS. NORTHINGS EaST,NGS 6 , 023,586.20 §71,864.47 6 ,023,888.§8 571,992.42 532' 979' 6 ,023,656.07 649' 950' 6 , 023 ,772.38 1037' 6 , 023,424.25 416' 1008' 6 ,023,540.44 II0' m 935' 6,023,013.86 814' 702' Bgl' 862' c:,7 3' SCALE IN I~aiL.F_.S SEC. la SEC. 19 CON OC0 LIIL NE POINT UNIT £XlSTING OIr VELOPME NT HOTF..~;: I. SIA'T[ PLANE CO ORDINATJ[S ARE' ZONE 4. 2. ALL GEODETIC POSITIONs ARE BASED ON N.A.O. 19Z?. OFFSETS TO SFCTION LINES aRE COMPUT£O BASED or,' PROTRACTED VALUES OF THE S [ CTIOINI CORN[ R POSITIONS. 4. LOCAi"[O WI1,HIN SECTIOH 18 8 Ig, TI3 N,RII[,UM ,AK. ,023,9~§.01 024, 004.84 G. oz4..o51.o3 I H~[I~I~Y C[RIIFY THaT I AM PROI'[RLY R(C~S1ERI~D AND LIC[tJSEO 10 PRACTICE LA~O 5UevfY~NG IN tHE 5/~T( OF ALASKA GEOOETIC §72,113.60 LATITUDE 70028' 29.019" N. ?cf' 28' 31.98t" N. POSITION LONGI T UDE -- ir1 149024' 46. ?03" W. 149°24' 42.8§4"W. DATE 6.2,85 6.2,85 CH[.CK£O ..i_ - J.B.S. 10. 23,85 J.B.S. rilELO BOOK 21 5T2 ,052.77 ?0028' 29.688'N. 149024, 41. 146" W. 6.2, as J.a.$. 21-8§ 572,022.58 713° 28' 30.8 35"N. 149°24' 42. 001" .W. 10.23,8§ B.T. 39 70028' 27. 402!'N, 149°24'39. 42 3"W. B.T. 39-85 572,083.38 70°28' 2:8. 548"N. 149024' 40.279" W. 10.23,85 B.T. 39 -8§ 572,013.88 70°28' 23. 376"hL 149024, 42.472"W. 10.23,E5 B.T. 39-85 70e28' 32. 458"N. 149°24' 49.280"W. L.O. 70°28' 33. 127"N. 57 t, 7T"J.46 !0.12,8§ 39 - 85 II. 15,85 L.O. 39 57 I, 96 I .74 S71.743.44. 149° 24'43. 723"W. t Ac/". ' Z4.-5o. I~o ~. ! hul, . . HHSU&' (NGf~( ( RS ANU ~RvE _ _~ i_ "7o'.zsL33.Gc~ N. 'B' PAD /NS. BUILT ~[LL LO¢*I'ION Survefed foF CO N OC O SCALE : i s,,([,, I" · 400' Il 2 O~r 3 COMHENTS ' ~.ECT. fg, A~L ~HERS ~RO~S. LJI/L tl~. II , , S~C. I8 ,SEC. H~- - o NOTEI~ .- I. STATE PLANE C0-ORDINATES ARE ~0NE 4. Z. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF' THE SECTION CORNER POSITIONS. · ' ! MILNE PT. UNfT ~OUNOJLRY ~ .... .- · ,..- ..- . ii' ~~'~_ "~T~ ............ SCALE ~ ~ ~0 N OC0 ' MILN[ r01NT UNIT -- ' EXISTING DEVELOPMENT LOCATION L,f S£CTION FROM ~J. LINd Ic~ W. ONE m 'TGS' 532' 6-tG j zUG' il.": 1"' I"' t -079 -O.SO' 1057-'- - Ioo$ STATE PLANE CO'O RD~. NORTHINGS G, ozS,-7oz. G. OZ3 ,-;7P-.Z:~.-/ 4:, OS3,4Z4.. G oz~, 540.P_S I I,~[REBY CKRTIFY THA~' J ~[ ~1~'"~ Z 'R~.O AND &NO ffH~t TH~ PLAT flEPRESENT5 A LOC~TtON ~URVEy ~DE ~Y ~E OR UNDER AND OTHER ~TAIL~ ARE CORRECT. EASTINGS 571, ~34.7-1 571109Z.~-~- 57~,o~ 572.oz~,&$ - 57~, 113..4S S7z. oB:~. Zo · , , {:;EOB[TIC POSITION . LATITUDE' j LONC, IT UDF - '7o'.Z~L ~o. tb~ I 149: 7o'- z$',. -31.;O,gi'-u I [49''' z4 '-4Z .$S,4 ~ ";0'- Z.$'- ?..9.&,9t Hj 140; Z.4.',41.141 ~ 7D': 2&'- ZT. 4o1: DATE '-u-%- $4 CHECKED 70'-Z,S'-Z&S4-&' I49'-Z. 4'-40.P_6St,, )1---3-,~4 j. N .- --' ' 'B' PAD __ &S- {~4J4LT ~'£LL 4.OCATI O~ CONOCO ~[:ALIr ::..' j ,SHF.£T ~ I' a 400' ''Z Or 2 CO Iai4 £ N TS; · 'D~ENSION THU~'~ FRC~I'N. LtNE EECT. 19, ALL ~HKRS FROM S. LINE SECT. le. I HOR I ZONTAL PROJECT I ON SCALE IN. - 1000 FEET CONOCO. !NC. PAD B. WELL NO, 12 PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK, INC. 4000 ~000 2000 1000 1000 2000 TARGET TVD=?134 DEP=2230 NORTH 2215 WEST 261 WEST-EAST 1000 0 [ I TD L ( ~SURFACE / 1000 I TARGET LOCATIONt 2300' FNL. 4550' FEL SEC. 18. TI3N. RIlE 'SURFACE 1..13CAT'tOtl, 765' FSL. 4289' FEL SEC. 18. TI3N. Rl lE N 6 DEG 2230' (TO 43 MI N W TARGET): I-'AD B. WELL NO: 12 PROPOSED MILNE PT., NORTH SLOPF- ALASKA EAST~^N.UHIPSTOCK, INC. 0 . SURFACE 1000 _ 2000 _ ~000 _ 4000 _ 5000 _ ~000 _ 7000 _ 8000 KOP ~0 30 TVD=3000 TMD=3000 DEP=O BUILD 2 1/2 DEO PER lO0 FT EOB TVD=4242 TMD=4312 DEP=366 ~' 9 5/8' CSO PT TVD=4719 TMD=4880 DEP=673 AVERAGE ANGLE 32 DEG 4t9 MIN TARGET TVD=7134 TMD=7754 DEP=2230 'TENTATIVE' TD TVD=7470 TMD=8154 [JEP=2447 I I 1 1000 2000 3000 VERTICAL SECTION 700 400 __: 300 _ 200 _ 100 _ m 100 _ 200 _ ~00 _ 400 _ 500 600 I I'qUK I i-1 500 400 300 200 100 I ! I I I 2271 ............... -:--"-:--' '-;r? .... CONOCO. INC. PAD B. WELL NO, 12 PROPOSED MILNE PT., NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK, INC. NOTE, WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 0 '4O$9 3878 'i £RON ~IUD PU~IP KILL MANIFOLD .... ' . FRO,~ REHOTE HIGH ' · PRESSURE PUMP --'-- REMOTE PRESSURE GAGE SENS~ NOTE: ' ' ~ HYDRAULIC CONTROLLED L ~UL~C C~L S~STEW FO~ B~ ~C~ ~ C~O~ ~ REMOTE OPERATED ~h~OLO TO INCLUDE (5) 5TATI~ CCNTROL ~ANIFO~ · ~T[O REUOTELT %ITH 3~0 PSi ~CCU~ULATOR a I~ G~. ~ESE~,g~R 8 AUX. ENERGY SOURCE. iS] 5[&. ~ROL W~KIFO~ PLUS V~RI~8~ C~OKE ~HT~L TO BE ~TEO ON RIG FLOOR. ~ DRILLING 4 ~E ~IFO~ SIZE- RATIN~ 3'- 5~0 --' ~ HYDRAUUC ~NTROLLED REMOTE PRESSURE GAGE SENSOR , CHOKE ADJUSTABLE ADJUSTABLE MANIFOLD CHOKE CHOKE I VARIABLE CHOKE REMOTE CONTROL TO SHALE SHAKER BLEED LINE TO ATPlOSPHERIC ;~. ? % r'-., --. j (., {? CHCKE 5 KILL MANIFOLDS FOR cls/8'~ & 7" OD CASING BOP STACK SO? t, ANIFOLD LAYOUT - CONOCO, CONOCO MILNE POINT LrNIT 20" DIVERTER STACK 6" Relief LLme ! 'Annular .- ! Preventer ! Valve lng [ Valve 6" Relief Valve '~ )Spool / 2000 p~ Diverter Quick' t Assembly S aver Sub Assembly Scarring Casing 1. Relief lines from the drilling spool will be routed for do~nwind diversion. 2. Hydraulic control system will be in accordance with APl specifj~aations and AOGCC regulations. 3. Both ttCR valves will open when the preventer closes, then either one may be closed. Desending on rig contracted, the two 6" lines mav he replaced by a single 10" line with a downstream tee. DRC 7-17-84 MILNE POINT L~IT BOP STACK ~ ~Flow Line F~ll-up LLne~ ,, ) - ooo l ~)SPOOU~ 3" - 5000 Side Outlets . Side Outl~.~S~OO:~ 11" - 5000 Siaa Outlets[ ....~ 1.] )8[~ ~~~~ (I) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated ...... (2) BOPE to be operated on each trip ..-- & pressure tasted weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 · gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperatety to meet APl RP 53 class 5M requirements. ~~~CHECK,"LIST:,~FOR,iNEW-WELL PERMITS .... ~" . ' C,o~mpany ~~ ~ Lease & Well No. ITEM APPROVE DATE YES NO . Loc (,~ thru 8) . 3. 4. 5. 6. 7. (8) (3) Admin ~D-~-~ V-%z6-~" 9. (9/ t%ru 12) ]0. 12) ]2. (4) C asg.'~z?~'~ ~d) ~/z~3'~ .. (1'3 t~ru (22 t~u 26) ]3. 1.4. t5. ]6. :7. ~8, 20° zl. 22. i::3. i.:4. 25. Is the permit fee attached .................. ~ .................... ,./~.- Is well to be located in a defined pool ............................ ~_~ Is well located proper distance from property line . Is well located proper distance from other wells ........ Is sufficient undedicated acreage available in this pool ........... Is well to be deviated'and is wellbore plat included ................ Is operator the only affected party .......................... ..~ ..... Can permit be approved before ten-day wait ............ · '. ...........__ Does operator have a bond in force ................................... ~_~~ Is a conservation order needed ...... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Q~_, . Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface.. ........ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... .Will'all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore : ......... .... Is'old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ........ .................... Is a diVerter 'system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating - Test to ~O psig ..~ Does the choke manifold comply w/API RP-53 (Feb.78) ................ Is the presence of H2S gas probable ................................. Additional requirements REMARKS o ~z H 0 02 ~-2 Additional Remarks: Geo lo.gy: Engij~eer ing: HWK ~ LCS ~ .C~BEW-__~'~ WVA MTM/'~,2 HJH ~ JAL rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS. AREA NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. / . Mì&... e... .Jl","hf B. -IJ.. C/J¡D€11 hd/~) - J:FO~611 , . DIRECT - DI GITAL LOGGING - Â ¡¡¡. I- ~ ~ :b. RtI . ~ ..:':b COMPUTER PROCESSED ANALYSIS If:::~;;¡ - ~ -.........; ¡ /I ~ g. {!J is- :.'j Company COHOCO IHC. Well MILNE POINT UNIT 8-12 \ Field KUPARUK RIVER DATE OF JOB: 05-10-85 , County NORTH SLOPE State ALASKA ColJnt.r~1 USA CLIENT FORMAT DATA TA'PE LOG INFORMATION STANDARD FORMAT ( L. I. S. ) '~"""""""""""'" '."",""".,"""-""" '-"'-"~"-""."'" """""""'-' .,.".." ",..,.."",."""'" '."'-"'""""""",""""'..",,..,.,.. '."-, """"'.", """"C' "".,."."""""'.'" ,." """."""."""""""""'.""""".'" ,0'" ,..""""""-" -" .-'°," -" "C"'.,.".""."",-" "","",..." ."."'.,." '.""'" ,.... '.",".'...." '-'"' """-~-""""'-""""---"~'----"'-"-'-' Me!! No.: CONOCO 812 Name:: MILtiE POINT UNIT 8-12 Date: 31 MA"f'. 1985 -. -- . De:pt.hs: 1999, OQ. t.o 7'981 .00 Field: KUPARUK RIVER , ,DATE OF 1..108: 05-1 (1-85 Time: 9: 55 AM FJ;U. Page: 1 L. I. 8. TAPE RECORDS liliARHART """"""",,""'"""""'-"",""" .'.." """"'.'."":"""""-.""""". "'.""""'."'.,, , ."""""""""""""'."'0""""""".""""""'.""."""'"""""""""""""',"" ""'.""""'."'",-' '.".""" '." '.""".""",,""."" "'- """"""""""""',-"...." .""'."".""""""""""""'" .",""'.."'",,' , ."'"," ."""""""""""" "."" -"""'."--""""""""-"-'~-'-"""-'----' .""""-'."""""'--"'.."""""" """"""""""-" , HEADER RECOR[:'S ~al;;,:4e: 2 k********************** ~*** REEL HEADER **** ~********************** Service name: &G5FO1 Date: 85/05/31 Origin: Reel name: 51185 Continuation #: 01 ------ -------- ---- -------- -- Previous reel: Comments: -------- -------------------------------------------------------------------- -********************** ~*** TAPE HEADER **** -********************** Service name: &G5FO1 Date: 85/05/31 Origin: Tape name: 51185 Continuation #: 01 ------ -------- ---- -------- -- Previous tape: Comments: -------- ----------------------------------------------.---------------------- ~* EOF *** GEARHART, -"'~.~"'" ~"'-'~"'" '~" ""'-' -" ,0"'... ""'""'" """,-"".0"" ,""" '~'"'""""""-"""'""" -"""""""""."""""""'" ""'-"..."."" -""."-""""""" ,....."....,., .."""""""""""""""""""',,'.""""""',,""""""""'-'""""..."..'...".",,' .""""'-"'.""..", -" ".""'.",..."'" ""","".,.,,"""'" '..' ""'-'-,"--"-"-"'",'--,"-"'-'~"-"" ,-.""..... ...' .",-,.,..... ."...., ..." . , HEADER R'ECORDS F'at;J€ :3 ~********************** ~*** FILE HEADER **** ~********************** File name: &G5FO1.001 Service name: Version #: Date: ---------- ------ ---- -------- Maximum length: 1024 File type: LO Previous file: ------ -- ---------- GEARHART -".".".,,-' ".... ,,",,""""'" ,."""."".""""""" .', """~"'.""""'." ,,-'" ,~",.".,..""""-,,,.,., ""',.. """""."".""'-""""""---"""-""".""'.""'-"-'"""""""""""""."""."'-""",'-"""."""""'.""""""'..""""'."""."""""'"".."""""""""""".""""""""""""""""""""""',"""""""""""""""""'"""'-'"",,, ""..,""...""", -"""'."""""".""""-"'"""""'-""""""""""'-.-""""';""""-""--.-.'~-..,.._,.""""""""""'-"."'-""""""~" I NFORMAT I I)N RECORDS Page 4 MHEI"1 CONTENTS UNIT T'r'PE CATG SIZE CODE ---- -------- ---- ---- ---- ---- ---- CN CONOCO INC. , . . . , . I . . I . , . . . , 0 0 40 65 Wt.¡ MILNE PO IN T UNIT B-12 . , . . . . . . . . . , . . . . 0 0 40 65 FN i<UPARUK RIVER DATE OF JOB: 05-1 0-85. , . . . . " . . . . . , . . 0 Ü 40 65 COUN HtJRTH SLOPE . . . . . . . . . . . , . . . . . . . . . . . . . . .,. , , . . . . . . 0 0 20 65 STAT ALASKA . . . . . . . . . . . . . . . . . . . . . I . . I . . . . . . . . . . , 0 0 20 65 CTRY USA . . . . I . . . . I . . . . . . I . . , . . . . . . I . , . . . . . . I 0 0 20 65 SECT i8. . . . I . . . . . . . . . . . . I . I . . . . . . . . . . . . . . , . . . . . . . . . . . . . . I . , . . û 0 :2 65 TOldN 13H. . . . , . . . . I . . . . . . . . . . . . . . . . . . . . . . . I , . . . , , , I , . . . . . . . , , , 0 Û 3 65 RANG 1 iE. . . . . . . , . . . I . . . . , . . , , . . . . , . . . . . , . , , . , . . , . . , . . . . . . I 0 0 3 65 EKe 59.000. . . , I . , , . I , . , . I . , , , . , . . . , . . . . . . . . . . , I . . , . , . . . . . , . FT 0 3 4 68 EDF 58.000. . . . " . '. . . , . , , . . , . . . . . , . , I I . I . I , . . . I . , . . . I . , . . . . . . FT Û :3 4 68 EGL "4 000. . . . . , , I ' . . . " . . . , . I . . . . . . . I . . . . . I . , . . . FT 0 3 4 68 - . . . . . . . . , . . PD St. 0 3 .-, 65 . , I . . . , . I . , . . , . . . . . . . . . . . . I . . . . . . . . I . . . I . , . . . . , . . , . . , ¡;¡:, LMF ~~8. . . . . . . . . . , . . . . , . I . . . . . . . . , . . , . . , . . . . . . . . . . , . , . . . , . . . . 0 :3 2 65 DMF Ke. . . . I . I , . . . , . . . . . I . . . . . . . . . . . . . . . , . . , , . . . . . . . . . . . . . . . . û :3 2 65 RUN 1 . . . . . . . . . . . , . , . . . . . . . . , . . , . . . I . . . . . , . . . . . , . . . . I . . , . . . . . (I 0 2 79 Lce 30. . . . . . . . . . . I . . . , . . . . . . . . . . . . . . . . . . . . . . I , . . . . . , . . . . . 0 0 :2 79 SOH 51185 . . . . . . . . , . . . . . . I . . . , . . . . . . . . , . , , . . . . . . . . , . . . . . . . 0 0 1 0 65 LUN 7612 . . . . . . . . . . . . . . . . . , , . . . . . , . , . . . . . . . , . . . . . . . . . . 0 0 i Ù 65 FL NORTH SLOPE . . . . . . . . . . . . . . , . . . I . . . . . . . . . . . . . , . . 0 0 20 65 LUL .-40 R T H SLOPE . . . . . . . . . . . . . . . . . . , . . . I . . . . . . . . . . . . . 0 Ü 20 65 ENeI HUPP . . . . . . . . . . . . . . I . . . . . . . I . . . . . . . . . . . . . 0 0 20 65 WITH BENDA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . , , 0 0 20 65 DC 7964 . 000 . . . . I . . . . . . . . . . . . . . . I , . . . . . . . . . . . . , . . . . , . . . . . . . . FT 0 3 4 68 DC 7966.000. . . . . . . . . . . . . " , . ." . . . . . . . . . . . . , . . . . . . . , . , . . , . . FT 0 3 4 68 TLI 1992 . (tOO. . , . . . . , . . . . . . . . . . . . , . . I . . . . . . . . . . . . . . . . , . . . . , . . FT 0 3 4 68 eLl 7962.000. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . . . . . , . . FJ 0 3 4 68 rcs 1 400 . (tOO. FIR 0 .") 4 68 . . , . . . . . . . . . , . . . . . . . . . . . . . . . . I . . . . . . , . . . . . . . . . . .:.. TlAB 2328 .(1'00 . . . . . . . . . . . . . . . . . . i . . . . . . . . . I . . . . . . . . . . . . . I . . . . . HR 0 4 4 68 BHT 151 . 0'0'0. . . . . . . . . . . I . . . . . . . I . i . . . . . . . . . . . . , . . . . . . . . I . . . DEGF 0 1 4 68 MRT 151 .000. . . 'I . , '. . . . . . . . . . . . . . I . . , . . . . . . , . . . . . . . . . . . . . . . . . . DEGF 0 1 4 68 MT GEL 0 .-) 20 65 . . . . . . . . . . . . . . . . . . . . . . . , . . , . . . . . . . . . .::.. M9S FLOWLINE . . . . . . . . . . . . . . . , . , . . . . . . . . I . . . . . . . , 0 ;2 20 65 MVIS 0 ..0-00. . . . . . . . . . . . . I . . . . . . . . . . f . , . , . . . . . . 'f . . , . . . . . f . . . . . . CP 0 ;2 4 68 RM 1 a 30. . . f f . . , . . . . . . . . . , . . . . . . . . . , . . . . . . . . . . . . , . . . . . . . . . OHMM I) 2 4 68 RMF 1 . ,740. . . . . . . , . " . . . . , . . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . . , . ,OHMM 0 2 4 68 MFST 64.900. . . . . . . . . . . . . . . . . . . . . . . . . . . . . f . . . . . . . . . . . . . . . . " . . . DEGF 0 2 4 68 MFSS MEAS. . . . . . . . . . . . . . . . . . . f . . . . . . . . . . . . . . . .. . . . . . . . . (1 :2 12 65 RMC 2.370. . . . . . . . . . . . . . . . . . , . . . . . . . . . . . . , . , . . . . . ., . . . . . . . . . OHMM 0 2 4 68 MCST -7?"O DEGF 0 :2 4 68 b ' ..0 " " " " " " " " " " " " " " " " " " . . . . , . . . . . . . . . . MCSS MEAS. . . . . . , . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . 0 :2 12 65 IiIiARHART "."""""'"-",_."""-,,..,""""'" """"""",""""""","",""'.'",.-".."",."""".,, '-"""" ,""',"""""""..."", '.' """"""""".""""""""""""""""""""""',.."""""" ",'" .""""""."""""'" ,""-'-"'."',"""""""",....." ."',""""'" """.',, ."""." "',,' ,...".", ..,'"..'""",""""'-"",'."",..","'.""'" ,..'" .".'." ."',,""'-- ",",""",""-'. .. ' ",... --,-'..... '",""'-""-"",-"-,_.,--,-"^""",,,,-,, .."" r'_,' "",",,' ."'. ..."" -' COMMENT RECORDS P .~I;;Je 5 ******************************************************************************** ******************************************************************************** ** This LIS tape was written by Gearhart Industries Wireline Services. ** ** All curve and tool mnemonics used are those which most closely match ** ** Gearhart curve and tool mnemonics. ** ******************************************************************************** ******************************************************************************** GEARHART TO SCHLUMBERGER MHEM SERYICE UNIT MHEM SERVICE UNIT ------ ---------- -------- ---- ------- ---- DEPTH FEET DEPT FT SP MERGE API SP MERGE API GR MERGE GAPI GR MERGE GAPI ILD MERGE OHMM ILD MERGE OHMM I LM MERGE OHMM I LM MERGE OHMM LL3~MERGE OHM,.1 LL3 MERGE OHMM CILD COMPUTED "MHO CILD MMHO TENS MERGE MY TENS MERGE MY IiIiARHART "-'-""'" ',-.. """"'~ """""'--""""-"" ...", -"""'-" ""..."""""""",.......,..".."..", ..", "".""""""""~""""""""""'""""""."....".""""""""""""""""."""""""",""" ,,""',,',,""'"""""""""""" "'.."'.",, """"""""""" ",'", "" """"", """"-""""""",,"""""""""""'-"""""" ."",," .." "-'..".""""""""'" "'" ,..",~"",_."""",-""""""""".",, ""'."""'"."""'-"'."""'---'-"""""""""-.--"".""'-" ,""""""""""",,"""""".'-""""'-'. DATA FORMAT SPECIFICATIONS p .=.~e: £. ~***********.*********** ~*** ENTRÿ BLOCKS **** ~*********************** ENTRY TYPE SIZE CODE ----- ---- ---- ---- 0,...........,............,....... 0 1 66 ~*************.*************** ~*** ENTRY BLOCK LEGEND **** ~***************************** TYPE DESCRIPTION ---- ----------- 0 Terminator ( no more entries) "~~""""""'" "-"""'~' ,,","" '."" ,.""'~.'...... ."',,-'" ","" ,-- '-""""".."" ","' "",.. '.." """-' "."""~""""""',,""" "'-'","",,"'.,,"'-" .-.."".,. "", "'," ,"""""'.""" ,"'- ,""""-" -.." ..-.'" ,.." ,"""""',~"",""""""'-'" ',,"" "'-"","" ,."-."",,,-- ."""""" ."" ,..'" ,.","." '",.. ,..""""'" ","",""" '..."'",- ""..' "",,,-.. -, ..."",- -"""~'-","",'-"-".,.."".~_..,."-,,.....- '.....-..... -, """.." .",," """" ,"'.,..,- ,..- DATA FORMAT 'SPEC I F I CAT I O~~S P .a I;] e: 7 (:tc************************************ fc*** DATUM SPECIFICATION BLOCKS **** fc************************************* SERVICE SERVICE API API API API FILE PRC # MHEM ID ORDER # UNIT LOG TYPE CLASS MOD :it SIZE LVL SMPL RC PROCESS INDICAïüRS ---- ------- ------- ---- --- ---- ----- --- ---- ---- --- ---- -- ------------------ DEPT 51185 FT 0 0 0 0 0 4 0 1 68 000000 000000 000000 SP r1ERGE 51185 API 20 10 1 0 0 4 0 1 68 000000 000000000000 GR MERGE 51185 GAP! 20 54 1 0 0 4 0 1 68 000000 000000 000000 ,ILD MERGE 51185 OHMM 20 120 46 0 0 4 0 1 68 000000000000 000000 ILM MERGE 51185 OHMM 20 120 44 0 0 4 0 1 68 000000 000000 000000 LL3 MERGE 51185 OHMM 20 220 6 0 (I 4 0 1 68 000000 000000000000 CILD 51185 MMHO 0 6B 46 (I 0 4 0 1 6e 000000000000 000000 TENS MERGE 51185 MV 20 0 0 0 0 4 0 1 68 000000000000000000 Ii IiARHART '-'"""'."~"""-""-"".""""""""""""'"" DATA RECORDS P .:= 9 e: .-, ,=, DEPT SP GR ILD ILN LL3 GILD TENS - - 7981.000 0.000 0.000 1.000 4 ":)76 1 .000 1000.000 -1190.000 . ,--, 7881.000 79.700 83.400 5.093 4.808 4.688 196.336 278.000 7 78 1 . '0 0 0 86.200 76.400 6.194 5.483 5.483 1 61 . 436 326.000 ~ 7681.000 99,500 '~5. 300 2.393 2.244 2.218 417.831 307.000 7581.000 91 .900 1 06.400 2.805 2.661 2.489 356.451 239.000 7481,000 '36.700 99. '300 i .592 i .578 1 '::;':'4 628.058 307.000 . I;;¡ çJ 7381.000 92.400 83,200 2.371 2.388 2.323 4" 1 69" 234.000 .... . ... 7281.;000 92.400 1 6 0 . 40.0 2,472 2.265 2.393 404.576 73.000 . 7181,000 88,300 159.500 2.710 2.570 2.972 3¡:;89"'" 190.000 . -' , 'I 7081.000 89.10-0 100.900 2.938 2.735 2.985 340.408 136.000 6981.000 87.400 96,800 3.707 3.573 3.396 269.774 112.01)0 6881,000 '34 .7;0 0 103.900 2.296 .j 26C'. 2.844 435.512 122.000 .:::. . :::J 6781 .0 00 93.400 77.900 2.094 2.070 2 .1 73 477.529 78.000 6681.000 89.600 SO , 500 3.090 2.951 ., 7'6 -¡. 323,594 -4.000 .:::. . 1 6581.000 91,900 72.300 3.733 3.491 ""'1 ,-.") -j¡:;~ 91'" -14,000 .j; " b.:.. .:::. ;;;s i .. 1 6481.000 92,800 72.400 2.924 2.786 2.812 341.980 -43.000 G ."" "" .....,... """"""" ...'" .."" .""","""""",".""""""," """"""""""""""""""-"'."""".'"',,",,""""."'""""""""""",,'" ,""'" ".'" ,..'. ."r".'" ","" ."',,"',." ." "'.' ""'.."',""", ",' "'",'""",, '""""'" ..""'" ,.,."""",,"""""""" ."""""..""., "'" ","",," ""'""".""""r"","""",,.n_',."" ~""',"'--."" ,...' -"'-""'"'-'~""- ~' .",,-" '." . """." .""," .""" .",""'", DATA RECORDS . P.::.ge: 9 DEPT SP GR ILD ILM LL3 GILD TENS -- 6381.000 91.000 83.500 3.304 3.105 3.266 302.691 -87.000 6281.~00 89.000 78.80~ 3.758 3.540 3.681 266.072 -219.000 6181.000 89.900 75.500 3.177 2.979 3.062 314.775 -297.000 6081,000 91.000 81.700 3,034 2.831 2.972 329.610 -268.000 5981.000 91.800 82,700 3.062 2.793 2.951 326.588 -283.000 .5881.000 93.300 69.700 3.319 3.006 3.076 301.301 -439.00(1 5781.000 92.5~G 77.3tG 3.192 3,006 3.062 313.329 ~507.000 56e1.~OO 93.100 69.60~ 3.296 3.097 3.162 303.389 -419.000 5581.~OO 92,200 73.80~ 2,9a4 2.667 2.864 344.350 -610.000 5481.~OO 93.3~~ 83.80~ 2~972 3.006 2.858 336.512 -590.000 5381.000 92.9~t 8~.500 2.858 2.600 2.773 349.945 -610.000 5281.~OO 85.6~O aO.3tG 2.G65 2.421 2.931 484.172 -746.000 , 5181.000 50.3'00 66.50'0 2.163 2. 168 3.3'~6 462.381 - 766 , I) 00 5081 .'000 87.100 87.600 3.428 3. (190 2.904 291 r 743 '-775.000 4981.~OO 84.3Ø~ 67.100 2.667 2.636 2.606 374.973 -785.000 4881.~OO 66.70n 74.S0D 3.741 3.273 3.243 267.301 -941.000 . . ' IiIiARHART -"".","""""",..."""""....,."",,,~.,"," """""'."~"'~"-""'~"""""'.""""""""'."""""".""."~"""""""""".",,,""""'."""""""-""""'-""""""""".""""."""""""""""'."""'."'."""""""""."."""""""',,"'--"""."--'.""'-',,"',..""""'"'"""r'."""""""..".""'."""""'-"""',"'-"""."""-""-'"""",~-,-""""""""""-,-,.-~...""-"-.""",,,,..,,..,~..,,,,~,,"".,.., "",..,.",.."...",. "., ..".... DATA RECORDS P.3.;J€: 1 0 DEPT SP GR ILD ILM LL3 GILD TENS , . GEARHART '-"""""""""""""""~"',"""-""""""""""""""'"""""""""""""',""'."'.""""""""""""""""-"""""""""".""-'.""." """.."""".... ,.,'..",", """"""'" "'-.""""-"'."".".""--"".""'-.""".""""""."".',""""""""."",."."".".",.....,.",-"..""""._,."..,,,...-...,....,~"""",."-"_....",...."..,,~,,.,...,, TRAILER RECORDS P.al~e: i 1 ~*********************** ~*** FILE TRAILER **** ~*********************** File name: &G5FO1.001 Service name: Version #: Date: ---------- ------ ---- -------- Maximum length: 1624 File type: LO Next file: ------ -- ---------- ** EOF *** , GEARHART -",..""..,."",.""..",.., -"","",..,-"-'",.",,, _.""".""""",.""'-""'~".'.""""" -""'."""",""'."""'."."'. -",-"",.",-""""""""-""""""-"""""~"",-,,..,,,,_.,,,-"".'" '-'."",,""""'" ."""",."."""""""""""."""-"""'"",."""",,,,_. '.""'.""-""'."""-""'"'."""""""'-"""""-".""' ".'" .""""", "".""""'-.".' ""'" ..""""",".'.""',,., """""'.""""""--"--""""--""""""""'" """"'.'.""""---"""""""",""'"""."""."".""""",,, """""'."""""""." ., H E A D ER R E C: 0 R D S' P-S\ge: 12 ~********************** ~*** FILE HEADER **** .********************** File narne~ &G5FO1~OO2 Service name~ Version #: Date: ---------- ------ ---- -------- Maximum length: 1024 File type: LO Previous file: ------ -- ---------- , G IiARHART """"""""'.""-"""""""'-"-'","""-""""""""""" .".', """"","" ",,"', """"""""""'.""""""""'." -""""""""""""'-"","""""""""'~"""""""""""""'-'"."..,....,.." .""""""""'~""""'-"""""',"""""'_.'~""""-""'-"""-"-"~.'","""--""'.'._"""-"""""'" ""."'""'"",'.. INFORMATION RECORDS Page: i 3 MNEM CONTENTS UNIT TYPE CATG SIZE CODE ---- -------- ---- ---- ---- ---- ---- CN CONOCO INC. ................ 0 0 40 65 hlN MILNE paItiT UNIT 8-12 ....,.......,... 0 0 40 65 FN KUPARUK RIVER DATE OF JOB: 05-10-85.....".,...,... 0 Ü 40 65 COUN NORTH SLOPE .................................... 0 Ü 20 65 STAT ALASKA .......................,....,..,.... 0 0 20 65 GTRY USA. ..............................,..,., 0 0 20 65 SECT 18................................,.................,.,. Ü Û :¿ 65 TOWt4 13t~.............,........"................,..,..,...... 0 0 3 65 RANG liE................."...,.........,..,.................. 0 0 3 65 EKB .59.000.,..."....,..................................... FT 0 :3 4 6e E()F 58.0'00..................,...........,...............,... FT 0 :3 4 68 EGL .24.000................................................. FT 0 3 4 68 PD .SL...............,..................................... 0 3 :::: 65 LMF ¡<a,...............,......,..............................., 0 3 2 65 DMF .K8................,.......,.,....,...,...."........... Ü 3 :2 65 R U t.1 1 - . .-. - - ., ..............,.....................,..,..,............ u U ;;!; (':J Lce .30.............,..,.,................,................. Ü 0 :2 79 :--. - U 5.'1 "1 '85 - - , - - - 'BUt., ,,' """""""""""""""""""""""" U U 11) ó::a LUt..¡ 76'12 .,.........,........,..................,..,.... 0 Ü 10 65 FL NORTH SLOPE ..............,.......,............. Û I) 20 65 LUL HORTH SLOPE "..................,......,........ I) I) 20 65 -N-I HIIP- - - -- .~ I::.lå "",t-' ""',""""""""""""""'" ,0 U ::::0 ó~ 1.1" T" BE"H- , 0 . ., - - 5 wI r'1 OR .......,'............................ U ....0 b, DC) 7964.0(tO,.......................................,....,.. FT ü :3 4 68 - L ~ - ~- 0'0 0 FT " - 4 - - L) ...,66."" ........................,....................... U.!J b~ TLl 1992.'0::OiJ................................................ FT (I 3 4 68 eLl 7962.0'0.0'....,.,...........................,....."....., FT (¡ 3 4 68 TC:S 1400.,(t'O'O....,.....,.............,....................... HR ~ I) ;2 4 68 T'.' B '-'3'-'ö '0""'.0- HC"'. 0 4 4 ~ ö LA II.!.. .c:.;.o.,.u ,'.,....,................................,..,.... f"~ ' s,.¡9 BHT 151.:0,'00.............................,............,...... DEGF I) 1 4 68 M,RT 151.0:0,0......,.,.......",.................,............. DEGF 0 i 4 68 MT GEL .................."......"........ (¡;2 20 65 MSS FLOWLIHE ..........,..,............."....... 1);2 20 65 MVIS O,:(t:O,O.....................,...........,...........,..... CP' I) ;2 4 68 RM 1.83'("......,..,.,.,................,...................,., OHMM ü :2 4 68 ,RMF 1.74'0............,.............................,........ OHMM 0 ;2 4 68 MFST 64,.,9:0,0............,...............".......,...,........ DEGF I) :2 4 68 MF""'" ME"'-' U. '-1 .¡., S::C'. ',88 AS,. ...........,..........,..........,........... .:.. J.... V,;,; 'RMC 2,37,0...........,...............,...,.,........"......... OHM,M I) 2 4 68 ~1C:,ST 67.7',0.0.................................................. DEGF ü 2 4 68 M~~~ M_4-. 0 ~ i~ ~5 J"tl,;,,:).¡:) 1",t::.RS. ,"....,.................,...,...,.......... .:!. J.:!. t;., , lifiARHART ",,"," '.~".""'.""-'-"~"-'" '."""""""""""""""",,""""""""""""""""""-""" """"""-""""""""""""'0""-""'-'.."" """"""""",."""""",-"""""",""'-"". """","""'" """""" , .",." """..,.".""."."., "'"."" -,.,._...o--..,_.~..--._..._.."--._.....,"",~,.,-""..,..".,,..,.""...., , .""""'...'" CI)MMENT RECORDS P d,;;}e i 4 ******************************************************************************** ******************************************************************************** ** This LIS tape was written by Gearhart Industries Wireline Services. ** ** All curve and tool mnemonics used are those which most closely match ** ** Gearhart curve and tool mnemonics. ** ******************************************************************************** ******************************************************************************** GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MHEM SERVICE UNIT ------ ---------- -------- ---- ------- ---- DEPTH FEET DE?T FT TEHS1 MERGE MV TENS MERGE MY GR1 MERGE GAPI GR MERGE GAPI FFDC1 MERGE CPS FFDC MERGE CPS HFDC1 MERGE CPS NFDC MERGE CPS RHOS1 MERGE G/C3 RHOa MERGE G/C3 I)RHO 1 MERGE f:ì/C3 DRHO MERGE G.lC3 FOHL1 MERGE CPS FOWL MERGE CPS NCNL1 MERGE CPS HCWL MERGE CPS RAT1 COMPUTED RAT ---- CDLi COMPUTED PU DPHI PU HPHS1 COMPUTED X SAND NPHI PU -""'-",,.-' "'"'."' ...~".,.._",.,....."""."".."",.."..",."""""",,, ,",."....""",...".."."""" ..."."""",-"""..., """',,""'" .,,"'""" _..,...""... """"""""".""""""",....,...._,~"-"".",-""",..",..,.."-,,,,-"",-"-",--"",-",-_"_",-,-"""",-"""""",,,",,,'.""""'.'-,.""'"""-".,.,,.,,- DATA FORMAT SPECIFICATIONS P.agE: 15 ~*********************** ~*** ENTRY BLOCKS **** ~*********************** ENTRY TYPE SIZE CODE ----- ---- ---- ---- 0.....".......................... 0 1 66 ~***************************** ~*** ENTRY BLOCK LEGEND **** ~*******************.********* TYPE DESCRIPTION ---- ---~------- 0 Terminator ( no more entries) , .GEARHART ,~"', ......., ."..,." '.'.. ." """""'..,,,. .",'" ",......"', ."... .,.'..'."""""""'.,..~ .""""""""'""-"'" " -" '."-", -",-""",.. ,""""-""C., """"" "'"",."'C... ~"-_.-""-",.,,-""-'..,-." ..-',,"'-"""'-"~'."~"""""'--'-'"""-"'-".""'-""""'-'~-' ~~----",...,-".,......,.",'.'.' _"",."",..,..,--..-,....""..,..,.,..-.,"C"..-,_.._",.....,.,......-,...-"..",..,."",.".,..""""""""""',..,."-.,.,..,,... DATA FORMAT SPEC I F I CAT I ot~S Page: 16 -************************************* +:*** DATUM SPECIFICATION BLOCKS **** .************************************* SER\i I CE 8ERV ICE API API API API FILE PRC .. MHEN II.) ORDER i UNIT LOG TYPE CLASS MOD " SIZE LVL SMPL RC PROCESS INDICATORS ---- ------- ------- ---- --- ---- ----- --- ---- ---- --- ---- -- ------------------ DEFT 51 1 85 FT 0 0 0 0 0 .4 0 1 68 000000000000 000000 TEt4S MERGE 51185 MV 20 0 0 0 1 4 0 1 68 000000 000000 000000 GR MERGE 51185 GAP! 20 54 1 0 1 4 0 1 68 000000000000000000 FFDC NERGE 51185 CPS "0 98 2 0 1 4 0 1 68 000000000000 000000 a;;.' NFDC MERGE 51185 CPS 20 98 1 0 i 4 0 i 68 000000000000 000000 RHOB MERGE 51185 G/C3 20 94 1 0 1 4 0 i 68 000000000000 000000 DRHO MERGE 51185 G/C3 20 1 :J)O 1 0 i 4 0 1 68 000000 000000 000000 FCNL rtERGE 51185 CPS 20 78 31 (Ì 1 4 0 1 68 000000000000 000000' HCNL MERGE 51185 CPS 20 78 30 0 1 4 0 1 68 000000000000 000000 RAT 51185 ---- 0 0 0 0 1 4 0 i 68 000000 ooooo~ 000000 DPHI 51185 PU 0 0 0 0 1 4 0 1 68 000000 000000 000000 tiPH I 51185 PU 0 68 3 0 1 4 0 1 68 000000 ooooon 000000 '~'" "",-"'" .'~,."""" .'" ,.",.,-".,.".",~,,_., ." "C"'."""""'.'..""',.'.'.""""'.""-' .."~""""""~' ."'-""-'.' -'" '"'", ..'.'-'.""'.'. ,.."".".".' -' ..."..',.""',.,. ,.."...,..."..."".'", _._"_."."""~,,,,.-"_.'_.' '-"~".-"_.'-'~"_."-"-- ~""".."..."",-"-_._."..."-",._"..,.",.",-,.,,-,,,.....,.",,.".,~.,-,.,,"."'..'-'.' ,~. -'. -,..'" -" DATA RECORDS F'ð9E: 17 DEPT TENS GR FFDC NFDC RHOB DRHO FCt4L HCNL RAT DPHI NPHI - . 7981.000 -1312.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 -999 '~5 0 160.606 -999.250 ...., 7881.000 253.000 71.400 e 0 1 . 70 0 736.600 2. 184 , 113 107,'300 273.000 2.300 >:)8 >:)42 35.370 .::.. ..... 7 78 1 .0 (I 0 346.000 74.500 768.600 748.800 2.204 . 115 '39 , 0 I) (I 244.500 2.357 27.030 34.960 7681.000 297.000 94.100 "1199.900 863. '300 .:> (I 1 'j .168 73,800 .... . ,c;, 195.300 2.599 3'" . -? 42.520 . 8. bó t Ii IiARHART TRAILER RECORDS Page: i::: ø*********************** ø*** FILE TRAILER **** ø*********************** File name:: &G5FO1.002 Service name:: Version #: Date: ---------- ------ ---- -------- Maximum leng~h: 1024 File type: LO Next file: ------ -- ---------- ** EOF *** . G IiARHART ~-'~"""""'."".'~ ~"~""'" .", "",;, ,," "..,...."".,." ,,-, ~.",."~",, '." 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"."""""""""-"".""""""-".'~'""-,-,.,~,."..",,,-""""""""-".."~",..,.,.."""",,..,, """"'.."..-"""'" INFORMATION RECORDS Page: 20 MNEM CONTENTS UNIT TYPE CATG SIZE CODE ---- -------- ---- ---- ---- ---- ---- CN caNoca lNC, ..............., 0 0 40 65 WN MILNE POINT üHIT 8-12 ................ 0 Ü 40 65 FH KüPARUK RIvER DATE OF JOB: 05-10-85................ 0 0 40 65 COON NORTH SLOPE.....................,.......,....,. 0 0 20 65 STAT ALASKA .......,'............................ 0 0 20 65 - TRI..J U.- . - - - 0 - 5 L: "I;:SA """""""""""""""""" 0 U ;¿ b -E~- . - .. .. - -- ~L:I .1~.........."....,...,......,....,.....,........",.., U U ;:::: b:;:' TOWN 13~i...,.",....,........,.,............"............... 0 0 3 65 RANG .liE....................,..,..........,.,.............,. 0 0 3 65 EKe 59.0'0,0.....,.,...,.......,.........................,.... FT 0 3 4 68 EDF 58.0:0,0.,..,...........,...,.........,....,....,..,...... FT 0 ::3 4 68 ,EGL 24.0'00........,..,.,."...,..,..."........,.."........ FT 0 3 4 68 PD .:al....,...........,...........,......,.....,...."..... ü 3 :2 65 L~1F .Ke..............,..............,.."..,.....,.,........ 0 3 :2 65 DMF ~~B""""""""""""""""""""""""",.,.. 0:3:2 65 RUN "l................."......,.........................., I 0 0 2 79 L -. :-. - .. " .. .- '":: - L:L: ,$'U....,................................................, U IJ ;¿ (';:J SOH 5,1185 ....."........,..,....,........,..,...,......... 0 0 10 65 LU,;"¡ 7612 ..........,.......,........"................, 0 0 10 65 FL HORTH SLOPE ...,.,..........,......,............ 0 0 20 65 LUL NORTH SLOPE .........,..."..................... 0 0 20 65 EHGI HüPP """""""""""""""""" 0 0 20 65 WITH BENDA .....,..."".............,...,..... 0 0 20 65 ,DC) 7',64.'0'1)0......,....................,......,............. FT 0 3 4 68 r... L -:J.-., .."'... F T " 3 . " - 'v a"":Jbb."tJUU............,.....\...........,................. U. 4 61:: TLI 1982.'60,0................,...................,........... FT 0 3 4 68 eLl 7962.'O,:¡,)'û......."........................,.............. FT 0 3 4 68 TCS 14'00.000.....,.....,..,.........,...,....,.....,........ HR 0 2 4 68 TLAB 2328'.0'0"0...........................,........,.,......... HR Ü 4 4 68 BHT 151.'0"0:0...........,...............................""" DEGF 0 1 4 68 "",1'('1 151.",0:0,:0................................................... DEGF 0 1 4 68 MT' I""'EL . .-. .-, . " 5' 1"1 U ..........,......,.................. 0.::..::.0 b. MSS FLO~dLlt4E ......................,...,......... 0 2 20 65 .."VIS '(¡.:,,(to::Ð....,.......,...................,.................. CP 0 :2 4 68 ,RM 1.83':0........,.......................,.............,.... OHMM 0 :2 4 613 RfitF 1,74'0............,.......................,...........,., 'OHMM 0 2 4- 6'8 MFST 64.9-0,0.........,.......,."..............,...,............ DEGF 0 2 4 68 MFC'. -. ME""""" - .- 1""' ~5 I"I""S ,.,S,. .,..........,.............,................., IJ;¿ ¿ 0. "~M 1'\ .- 3:"':1 "\-HMM . .... - ... ,f".rtL~ 2."..I,::U.............,...........................".......... U,t"', U ;¿ 4 be: M -. ""'T .t" 7 '7,". r E'M.F . "- 4 -.- ,.,t.:~ t;.,'.tltO...................,................."........... LJ\.ì U::::: 08 M....-.-. Ml"",,-. , - .j ."- '"5 t.:S!:i "'I&;.:f(::). """""""""""""""""""""'" u.:;. 1;:::: b "'. ti EARHART "",,"'.'.'- "" ,,'. ,,",',',":' ,""'"': '.",.'" "...,."" ~""~.. ".' ,-""."'"..,, "",.' ""',,"'.' '.'^" "".., ~'" ",""". .".",~", '.'" "'.""" """","'.' '-""'.""""',-"""""" "'.".".'",,- """""'"^,,"""',,.-'."'. ,_.",~'. -"'~".."",r" """" COMME~~T RECORDS Page 21 ******************************************************************************** ******************************************************************************** ** This LIS tape was written by Gearhart Industries Wireline Services. ** *. All curve and tool mnemonics used are those which most closely match ** ** Gearhart curve and tool mnemonics. ** *************.**********~******************************************************* ******************************************************************************** GEARHART TO SCHLUMBERGER MHEM SERVICE UNIT "HEM SERVICE UNIT ------ ---------- -------- ---- ------- ---- DEPTH FEET DEPT FT TENS2 MERGE MV TENS MERGE MV GR2 MERGE GAP1 GR MERGE GAPI FCHL2 MERGE CPS FCHL MERGE CPS NCNL2 MERGE CPS NCNL MERGE CPS NPHS2 COMPUTED X SAND HPH! PU RAT2 COMPUTED RAT ---- DATA FORMAT SPECIFICATIONS F' "" .... -. '-J "j .;;¡¡ '::t \:::: .::...::.. ~*********************** ~*** ENTRY BLOCKS **** ~*********************** ENTRY TYPE SIZE CODE ----- ---- ---- ---- 0....................0............ 0 1 66 ~***************************** **** ENTRY BLOCK LEGEND **** ****************************** TYPE DESCRIPTION ---- ----------- 0 Terminator ( no more en~ries ) ""..,.""-.,.....",...",.""..",.~.,~,"".",-,.".,,.'"'..'.""'."""'.'",."""""~"""""""",,,,~-,..,,",.,"""0"'.""""""""."""-""'" """""""""""".""""""""'.""""."""""" ','C"""""""',"".'-"'~"'."'..'."'..","""-""'"""',",""~""."""'-"'.,"',"""""""'.'"~,"."",""",.."",.....'.'"' '"""",.'",""""'."""'~'" DATA FORMAT SPECIFICATIONS Page: 22 ø************************************* f<*** DATUM SPECIFICATION BLOCKS **** f<************************************* SERV ICE S.ERV ICE API API API API FILE PRC # MNEN ID ORDER # UNIT LOG TYPE CLASS MOD " SIZE LVL SMPL RC PROCESS INDICATORS ---- ------- ------- ---- --- ---- ----- --- ---- --,-- --- ---- -- ------------------ DEPT 51185 FT 0 0 0 0 0 4 0 1 68 000000000000 üOüOI)O TENS MERGE 51185 MV 20 0 0 0 2 4 0 1 68 000000 000000 000000 GR MERGE 51 j 85 GAP I 20 54 1 0 :2 4 0 i 68 000000000000 000000 FCNL MERGE 51185 CPS 20 78 31 0 :2 4 0 1 68 0 0 '0 0 0 0 0 0 0 0 0 û 000000 NCHL MERGE 51185 CPS 20 78 30 0 :2 4 0 1 68 000000000000 000000 NPHI 51185 PU 0 68 3 0 2 4 0 1 68 000000000000 000000 RAT 51185 ---- 0 0 0 0 :2 4 0 1 68 000000 000000 000000 . GEARHART "","""""""."""'.","',,"""""'-""""""." ,. "" ""',.." """'.""""""'.""""'.."."""'.'.""""'.-"""""'. ',,"'."..""" ,""""."""""""".""""",....""""" "."'-"""""""..."",..""",."."""."",.""""",,.... ""."."'.""'."""""'.""".""""""."",.,..,..."...""","""'."'" """,,"""" '",. """"'"""""""""""""""""'.""""""'."""'.;"'."'" ' DATA RECORDS P .::ì t;;J e: 24 DEPT TENS GR FCHL t~CHL t..JPHI RÄT - -. 4'314 . 500 -1019.000 0.000 0.000 0.000 -999.250 -'399.250 4814,500 -976,000 59.400 55 . 1 00 160.800 51 .250 .:) .:, 4 8 .::.. .... 4714.500 -971.000 54.800 51.500 156.500 49,250 2.934 4614.500 -1 049 . 000 40.500 50.000 149.400 47.140 2.891 4514.500 -1078.000 48.800 51 .000 155.100 48.360 ."") 9C"..1 .c;.. 1;;i,:;I 4414.500 -1088.000 40.900 54.500 151.500 50 .960 3.034 4314.500 -1156,000 43.700 47,900 136,700 49.6';0 2.953 4214,500 -'1137.000 '" 4:]. 4 00 57.700 172.100 44.020 2.756 4114.500 -1 1 46 , IlOO 29,200' 43,700 139.500 55.760 :3.163 4014,500 -1215.000 38,400 51 ..0,00 165.900 57.340 3.119 3914,500 -1254.000 43.400 45.200 138.500 53.230 3.088 3814.500 -1283,000 43.300 54.100 153,100 60.550 2.961 3714,500 -1312.000 45.700 43.1110 129.400 59.930 3,265 ,J 3614.500 -1371,000 42.700 34.700 123.100 75.260 3.620 3514.50.0 -1400.000 4 1 , 50 0 44.7:00 144,200 57.760 3.162 3414.500 -1483,000 44.400 45,700 146.300 66.310 3.255 -"..,' ,""',""""" """ ,..". "..",..."~,, ..""""""'.'.' ......",.,....." '-"'~.."""""""" "'.,..," ""', .'" """ . ""'" ,'.." '.""".."" """""',"'" ",."" ,,"""""'" '."'~"""'" ."',","'" ""', ."""""".."".'" ,-""'", .'"" """'..""',,""" .. ..'.'" ,'","" '.","'",".',,"'" """'."'.. ',...."...., -"'0"""" "..".., ..',," '..." "", ,,'" ""'."".""'.""""',,""'--- '-"",""""""""""""'"",,""'-"""",,"" ",'" .., .'." ""'..",,',," .."" .".....' , DATA RECORDS p .sa 1;1 E: 25 DEPT TENS GR FCNL NCHL NPHI RAT r 3314.500 -1507,000 52.200 43.700 132.200 62.420 3.193 3214.500 -1561,000 43.800 43.600 129.400 57.170 3.148 3114.500 -1605,000 30.500 36,800 122.100 6 1 .04 0 3.312 3014,500 -1639.000 46.400 50.900 146.100 64.630 3.360 2914.500 -1683.000 50,900 35,900 125.200 79.770 3.547 2814.500 -1712.'lOO 34.200 46.600 146.000 i 56. 11 0 3.156 2714.500 -1742.000 4 1 . 5 00 45.4,00 137.000 55.640 3.096 2614,500 - 1761 .00iO 31,200 48,500 141.500 56 . 1 70 3,099 2514.500 -1810.000 35.100 46.5,00 146.000 55.620 3.150 2414,500 -1834,000 33.000 47, 5:0 (I 148.000 63.630 3.244 2314,500 -1859.000 36,300 42.000 147.500 63.750 3.390 2214.500 -1893,00,0 40 .900 48 . 5:00 164.300 60 . a 30 3,215 21 14 . 5(1,0 -1917.000' 44 . 9("0 . 40.500 1 41 . 5 00 52.340 3.161 2014.500 -1 9 12 .000' 34.800 40.000 134,300 65.130 3 2 c-....... , ;:;:I, """""'~"""~""""~"""""..",,",- TRAILER RECORDS Page 26 ~*********************** ~*** FILE TRAILER **** ~*********************** File name: &G5FO1.003 Service name: Version i: Date: ---------- ------ ---- -------- Maximum len9~h: 1024 File type: LO Next file: ------ -- ---------- ft* EOF *** ft.********************** ~*** TAPE TRAILER **** ft*********************** Service name: &G5F01 Date: 85/05/31 Origin: Tape name: 51185 Continuation #: 01 ------ -------- ---- -------- -- tiexttape: " Comments: -------- -------~---------------------~--------~------------------------------- ".",~.""""..,. ,--' 'r"" ..~"",..~""-",..-,,,. "',""' "..,. ,""_.""-,.,,,,.,.,. ",""" ",-, ,"'., """"'"".""""""",',"'."-""'-"r,.."""""""'" ,~""- "..,...,,-- '."" ".,. ",." "'"" ,,"'.' '"""""""""'--~""",".",;".,-""-,...,, """"""""""".,-"-""""",---",""",",,,,,,w,,' ~"'~"',.'" ,""""'.""'-" ',",'" TRAILER RECORDS Page: 27 ~*********************** k*** REEL TRAILER **** ~*********************** Service name: &G5FO1 Date: 85/05/31 Origin: Reel name: 51185 Continuation #: 01 ------ -------- ---- -------- -- Next reel: Comments: -------- ---------------------------------------------------------------------- ** EOF *** ** EOF *** ,