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Home My WebLink About169-036MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission / David Joh~/~, Chairman~,~ Blair Wondzell, ~ P. I. Supervisor FROM: Chuck Scheve, ~- ~ SUBJECT: Petroleum Inspector DATE: April 2, 1997 FILE NO: y99kdbee. DOC Surface Abandonment Put River State/H PTD # 69-0036 Wednesday, April 2,!997; I traveled to ARCOs Put River State #1 location to inspect the casing cut off and abandonment of this well. The conductor and surface casing had been cut off at 5'+ below ground level and both were full of cement. A 3/4" thick plate was welded over the casing with all appropriate information bead welded to it. Gravel will be placed in the cellar and the location will need to be inspected this summer. Clean up operations were under way at the time of this inspection and only minor · amounts of trash remained. SUMMARY: I inspected the casing cut off depth, cement tops and the P&A marker plate on ARCOs Put River State #1 exploration well. Attachments: Pictures X Unclassified Classified Unclassified with Document Removed WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well Oil__ Gas__ Suspended__ Abandoned_X Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 69-36 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~ ~' 50-029-2001 7 4 Location of well at sudace~. 9 Unit or Lease Name 2343' FNL, 2436' FEL, Sec 7, T10N, R14E, UM. ,,~'~ Put River State (7-10-14) At Top Producing interval~ 10 Well Number N/A. ~. ! Put River State #1 At Total Depth 11 Field and Pool Same as surface Iocataion. Wildcat 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 70' RKB ADL 28313 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 5/12/69 6/15/69 4/2/97 (P&A'd). N/A 1 f 7 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 9903' MD / 9903' TVD P&A'd to Surface. YES_X NO_ N/A 22 Type Electric or Other Logs Run Schl DIL, BHC, FDC, HDT, PML, Velocity Surveys & CBL-GRN. ~t't I~ IA I ~23 CASING, LINER AND CEMENTING RECORD ~ U r~ I ~ i I~ ~ L, v _ SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 30" 157.5# B Surf 95' 39" 240 Sx Fondu 20" 94# H Surf 518' 26" 1290 Sx Fondu Fly Ash 13-3/8" 61 & 54.5# J Surf 2206' 17.5" 1216 Sx Fondu & 1000 Sx CIG 9-5/8" 40, 43.5, 47# N & P Surf 9895' 12.25" 680 Sx Fondu Fly Ash & 1300 Sx Cl G .~4 Pedorations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD None. RECEIVED 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1 6 1997 DEPTH INTERVAL MD AMT & KIND MATERIAL USED ~.laska 0ii & 6as Cons. u0mmis~.-' Anchorage 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned to Surface. Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GOR N/A TEST PERIOD __ Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) N/A 24 HOUR RATE __ - - 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-403 form approved 1/23/97 (Approval # 397-014). Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Top Cretaceous 2246' 2246' N/A 1st Coal Bed 4208' 4208' Jurassic - Triassic 8901' 8901' Sandstone Permo- Pennsylvanian 9882' 9882' Limestone 31 LIST OF ATTACHMENTS Summary of Put River State #1 Plug & Abandonment Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~ '~' ~ Engineering Supervisor Date ~ -/.~' - '~"7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. 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 cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none", Form 10-407 ORIGINAL PUT RIVER STATE #1 DESCRIPTION OF WORK COMPLETED PERMANENT PLUG & ABANDONMENT 3/14/97: M IRU & PT 13-3/8" casing to 2000 psi; passed. RIH & tagged PBTD at 226' WLM (no tubing in the well). RIH w/CIBP & set in the 9-5/8" casing at 189' MD. POOH & PT casing to 500 psi; OK. RIH w/tubing punchers & shot circulation holes in the 9-5/8" casing at 169 - 174' and 159 - 164' MD w/500 whp held on well. Saw no communication between 9-5/8 x 13-3/8"; suspected annular mud frozen. POOH w/punchers. 3/15/97: MIRU equipment. MU jointed pipe string & RIH to pump Hot Water to thaw 9-5/8 x 13-3/8" annulus. Annular pressure fell to zero, and established injection into 13-3/8". Circulated 75 bbls Hot Water, then swapped to 7 bbls Hot Oil, followed by 30 bbls Diesel for FP. 3/24/97: MIRU & PT lines. Circulated 3 bbls Diesel down 13-3/8" & up 9-5/8", then mixed & pumped 26 bbls of 15.7 ppg Arctic Set 1 Cement down the 13-3/8" to P&A the 13-3/8" x 9-5/8" annulus and the 9-5/8" casing to surface. 3/29/97: MIRU equipment. Verified no pressure or fluid in casings, then mounted saw to 20" casing & set up crane to attach to tree. Drilled holes in 30" casing; no pressure or fluid encountered. Cut 30" casing with torch to open 5' window and removed 30" to strap on guillotine saw. Cut through casings to cut off wellhead. Lay down wellhead w/crane. Tagged cement top in the 9-5/8" casing at approximately 40'. 3/30/97: MIRU cementing equipment. Tagged cement in the 9-5/8" at 50' and in the 13-3/8" at 6'. Pumped 5.5 bbls of Arctic Set 1 down the 9-5/8" and 13-3/8" casing while vac truck took displaced fluids from surface (witnessed by Doug Amos of AOGCC). 4/2/97: MIRU. gravel. Welded abandonment cap on well (witnessed by Chuck Sheve of AOGCC). Abandonment complete. Backfilled & graded Abandonment Cap Marked as follows: ARCO ALASKA INC, PUT RIVER STATE, 7-10-14 #1, PERMIT #69-36, APl #50-029-20017-00 2343' FNL & 2436' FEL of Sec 7, T10N, R13E, UM. State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~ DATE: Chairman THRU: Blair Wondzell, ~~ FILE NO: P. I. Supervisor FROM: John Spauldingf'ff.~,~ SUBJECT: Petroleum Inspb/ March 24, 1997 y991dzde.doc Surface Cement Plug Put River State # 1 ARCO Exploration PTD 69-0036 Monday March 24, 1997: I witnessed the Surface Cement Plug on ARCO's Wildcat well Put River State well # 1. The AOGCC Plug and Abandonment report is attached for reference. A bridge plug was set at150' MD perforations had been shot near the BP and cement was circulated down the 13 3/8" casing and back up the 9 5/8" casing to surface. The tree will be removed later and the casing cut a minimum of 4' below original grade with the marker plate welded on to the casing stubs. Summary: I witnessed the pumping of cement for a surface plug and abandonment an Put River State # 1. Attachments: y991dzde.xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA .4L4SK4 OIL AND GAS CONSERV.4TION COMMISSION Plug And Abandonment Report Operator: ARCO Operator Rep.: Jim Moore Lease No.: Well No.: Sec. T-R Total Depth: 9895' Date: Well Name: Put River State # 1 PTD No.: 69-0036 S. 7, T. 10N, R. 14E Meridian: UM Elevation: Mud Wt.: 3~24~97 PPg. CASING DATA: Drive Pipe: NA Conductor: 30 Intermediate: 9 5/8 O.D." Set @: NA ft. With NA Penetration O.D." Set @: 95 ft. Surface: 13 3/8 O.D." Set @: O.D." Set 6: 9895 ft. Prodctn: NA O.D." Set 6: 2206 ft. NA ft. PLUGGING DATA: t. Open Hole Plugs: 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: REMARKS: Bridge plug set at 150'MD with perforations in casing cement down 13 3/8" up 9 5f8" ' Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet " Casing Cut @ Feet Distribution: orig - Well File c - Operator c- DNR/DOG c - Database c - Rpt File c- Inspector Inspector (s) · ~¢/t,¢ '~, ~'~ FI-000 (Rev. 3/93) Y99LDZDE.XLS ALASKA AND GAS CONSERVATION CO ,tSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2343' FNL, 2436' FEL, Sec. 7, T10N, R14E, UM. At top of productive interval N/A At effective depth N/A At total depth Same as at the Surface Operation shutdown Plugging X Pull tubing Variance 5. Type of Well Development Exploratory X Stratigraphic Service Re-enter suspended well Time extension Stimulate Per/orate Other 6. Datum of elevation(DF or KB) " 70' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number Put River State #1 9. Permit number 69-36 10. APl number - 50 - 029-20017 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 95' Conductor " 518' Surface 2206' Production 9895' 9903 feet 9898 feet Plugs(measured) Cement Plug - P&A 'd in 1969 to 1988' MD. 1988 feet 1988 feet Junk(measured) Size Cemented 30" 240 Sx Fondu 20" 1290 Sx Fondu Fly Ash 13-3/8" 1216 Sx Fondu & 1000 Sx G 9-5/8" 680 Sx Fondu Flyash & 1300 Sx CIG Measured depth Trueve~ical depth 95' 95' 518" 518' 2206' 2206' 9895' 9890' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None ORIGINAL JAN Z1 1997 Alaska 0ii & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~ 14. Estimated date for commencing operation February, 1997 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~J..,~ '~. ~ Title Engineering Supervisor FOR COMMISSION USI= ONLY 'Conditions of approval: Notify Commission so representative may witness Plug integrity ,," BOP Test ~" Location clearance Mechanical Integrity Test Subsequent form required 10- Detailed operations program BOP sketch x. 15. Status of well classification as: Oil Gas Suspended X Date /-/~--?'7 I A row, Approved by order of the CommissiA~roved Copy Form 10-403 Rev 06/15/88 Returned Original Signed By David W. Johnston Commissioner SUBMIT I'~ T~PLICATE~ Put River State # 1 Intended Permanent Abandonment Procedure Objective: Permanent plug and abandonment to surface. . , . . Pressure test the 9-5/8" casing and previous cement plug to 1500 psi. Pressure test the 9-5/8 x 13-3/8" annulus {Not Arctic packed) to 1500 psi. Rig up Slickline and make gauge/tag run to PBD in 9-5/8" casing - est. 1988' - if possible. 9-5/8" casing may be collapsed due to mud freeze-back in the 9-5/8 x 13-3/8 annulus. Determine maximum tool size that will pass. Rig up E-Line. Punch 5' of circulation holes in the 9-5/8 casing at 155' below ground level, or as deep as possible above 155' if collapsed. RIH and set a 9-5/8" BP at 160' BGL, or as deep as possible above 160' if collapsed. Rig up CTU. Circulate hot diesel from the 9-5/8 to thaw mud in the 9x13 annulus. If possible, establish circulation down the 9-5/8 and up the 9x13 annulus. Circulate out mud with diesel. Lay in a 160' (11.7 bbls)* Arctic Set II cement plug from BP to surface in 9-5/8" casing and displace the 9x13 annulus with cement also (9.0 bbls)*. *These volumes reflect the ,9-5/8" casing not collapsed case. 5. Remove wellhead. Cut all casing strings 4' below original ground level. . Weld a steel plate across the conductor with the following information bead welded on top: ARCO Alaska, Inc. Put River State 7-10-14 #1 Permit #69-36 API #50-029-20017-00 7. Remove the cellar and backfill the hole to pad grade level. JAN / ] 1997' Alaska Oil & Gas Cons. Commission Anchorage January 15, 1997 SEC ?. TION. R14E CI[I, IENT ~ IN ~ X 13-3~' ESTUdATED T~ BE 21S' 13-3/8' OV (~ 1092' TCX~ m.UG ~ 19e8' (EST.') TOO RET, AJNEFi ~ 2258' · eeeet~e, ed, eoee · -- <-Y.<v:.'... .. ;;.';.'. ':,::::::::::::.:.. .... ;;;....;.'.. .... :'i'X'>?.' ---.-....Z<<.>Z. · · · e, Cd'eeOCe- '. · · .. ;:;.. 2O' (:SC3 ~) 618' 13-3/8' CSG ~t 2206' ~,3-a,'8- by @ ~3a~ TOO ~1 ANNLRJJ~ 0 8712' 907'0 TO 90~ '1'OO RETAINER 0 oo80* PERFS 609~- 9100' TWM/SAG/8-11-! PLGGING & LOCATION CLEARANCE REPORT State of Alaska ~u~ OXL ~ ~ CONS~VaTXON C~USSXON PTD No. 69 Lease /9~ Memorandum To File: API No. Well Name Operator Abnd Date Spud: ~-~2/W9 i, TD: 9 g(5 7 , Completed Note casing size, wt, depth, ~mt vol, & procedure. Liner: Perf intervals Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear, code. Well head ~t off: Marker post or piate: Location Clearance rom at A\gen\lo-eq~fm, zevS/Z4/95 ARCO Alaska, Inc.i Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, /- /'~.j~mes R. W'negarner, CPL '"' ~~'"Senior Landm~/ // JRW:hb Enclosures CC: M. L. Bill L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATe 1528 LAO 466 ATe 1918 ATe 1420 ATe 1202 ATe 496 ATe 1439 RECEIVED APR 1 4 1995 AlaSka 0il & Gas Cons, Commission Anch0ra:-'~ ARCO Alaska, Inc. is a Subsidla~J of Atlantic Richfield Company Exploration Wells (ARCO Contact: Tom McKay 265-6890) ARCO hereby requests extensions of "suspended" status for the following wells. West Mikkelsen State #1, APl # 50-029-20278-00, Permit # 78-0017-0 This well was Certified Capable of Producing in Paying Quantities on February 15, 1979. Hemi Springs State #1, AP! # 50-029-21056-00, Permit # 83-0181-0 This well was Certified Capable of Producing in Paying Quantities on June 4, 1984. Birch Hill 22-25, Permit # 65-1 This well was Certified Capable of Producing in Paying Quantities. Falls Creek #1, This well was Certified Capable of Producing in Paying Quantities on February 18, 1944. The following wells are scheduled to be plugged and abandoned: Delta State #!, APl # 50-029-20004-00, Permit # 68-0095-0 Delta State #2, APl #.50-0...2.9-2..0150-00, Permit # 74-0056-0 Put River State #1, APl # 50-029-20017-00, Permit #.69,0036~0 Kavik Unit #3, APl # 50-179-20004-00, Permit # 73~0027-0 Highland State #1, APl # 50-029-20199-00,, Permit # 76-0017-0 Ravik State #1, APl # 50-029-20888-00, Permit # 82-0218-0 Sag River State #1, APl # 50-029-20002-00,, Permit # ? Nodhwest Eileen State #1, APl # 50-029-20013-00, Permit # ? APR 14 1995 A~ska tlil & Gas Cons. Commission Anch0ra ~ The following well is no longer operated by ARCO: Swanson River Unit #34-15, APl # 50-133o10142-00, Permit # 60-0041-0 August 19, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14,33 TELECOPY: (907) 276.7542 David Sutter, Land Manager ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc. has 25 suspended wells as shown on the attached lists: ARCO SUSPENDED WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. . Chairman encls c: Blair Wondzell bew/llarsusp O~ H~ o o o o o o o o ~ o o o ~1 rt (~ OI rt (~ 0 E~ ri r4 rt 0 ri ri ri ri rt ri ~ H H H H o o ;:~ o o o o o o o ~ o~ o Q o o o o o o o o o, o o o o o o o ~ , , ~,~;~, , , , , , , , 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 u ~o~ ~ ~ , , ~ H 0 ~ 0 ~ ~ , H 0 ~ H 0 0 ~ ~ ~ H 0 ~ H H D H H H H H H H H H ~ _ ~ O O O O O O H O O O O H O O ~ O O O O O O O O O O O O O O O H 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ALA OIL AND GAS CONSERVATION COM ~,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend~[~,. Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~,,,Change approved program~'L~ Plugging ~ Stimulate [] Pull tubing ~ Amend order ~ Perforate ~ Other~)~ 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0. Box 100360 Anchoracje~ AK 99510-0360 4. Location of well at surface 2343' FNL, 2436' FEL, Sec. 7, TION, R14E, UN At top of productive interval Same as Above At effective depth Same as Above At total depth Same as Above 11. Present well condition summary Total depth: measured 9903 ' MD feet true vertical 9903'TVD feet Effective depth: measured 2256 ' MD feet true vertical feet 2256'TVD Casing ~ngth Size Structural 80' 30" Conductor 514' 20" Surface 2205' 13-3/8" P roducti on 9895 ' 9-5/8" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured, depth) None · 5. Datum elevation (DF or KB) 89' RKB 12.Attachments 6. Unit or Property name Put River State (7-10-14) 7. Well number 1 8. Permit number 69-36 9. APl number 50--029- 2001 7 10. Pool Wildcat feet Plugs (measured) CIBP ~ 2256'(100 sx Class C on To Junk(measumE~,,,.,/ BP (~ 9066'(100 sx Class G on T :None · Cemented MeaSured depth 240 sx Fondu 95'MD 1290 sx Fondu 518'ND 1216 sx Fondu & 2206'MD 1000 sx Class G 1300 sx Class G & 9895'MD 9895'TVD 680 sx Fondu True Vertical depth 95'TVD 518'TVD 2206 ' T VD RECEIVED JIJL - i 1988 Alaska 0il & Gas Cons. Commission Anchorage Description summary of proposal/~,. Detailed operations program [] BOP sketch [] Date Date approved 13. Estimated date for commencing operation Aucjust~ 1989 14. If proposal was verbally approved Stt~sequet3t Work ]{eporl~ oa Form No, ..... Dated .... /---7-.- Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)(~qJ~,_Y~~XJ Title Associate Engineer Commission UseOnly (JG) SA3/0014 by order of the commission 'Date 7-/~,- (~ Submit in triplicate Conditions of approval Approved by ORIGINAL SlGNEi) BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Notify commission so representative may witneSs I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned Commissioner p) op) APPLICATION FOR SUNDRY APPROVALS PUT RIVER STATE NO. 1 ARCO Alaska, Inc., requests an extension of "suspended" status for the Put River State No. 1 well. This well is scheduled for abandonment in 1989. ARCO Alaska, Inc., also requests an exception to the surface plug requirements of 20AAC25.110(c) until the well can be abandoned. The perforated intervals are isolated by cement and cement retainers. The well has kill-weight fluid between plugs and a non-freezing fluid in the annulus and the production casing above the top plug. SA3/OO14a 6/28/88 REEElVED J U L - 1 1988 Alaska. Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK .... L AND GAS CONSERVATION COMM ,_.ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~- Suspend ,~ Operation Shutdown m Re-enter suspended well ~ Alter casing - Time extension ~,,.Change approved program ~ Plugging ~ Stimulate ~- Pull tubing- Amend order' Perforate- Other ~,/,,. 2. Name of Operator ARCO Alaska, Inc 3. Address P- O. Box 4. Location of well at surface 7. 2343' FNL, 2436' FEL, Sec. 7, T10N, R14E, UN At top of productive interval 8. 5. Datum elevation (DF or KB) 89 ' RKB feet Unit or Property name P,,t River Rt-nt-~ (7-1{')-14) Well number 1 Permit number Same as Above Ateffective depth Same as Above Attotaldepth Same as Above 69-36 9. APl number 50-- 029 -20017 10. Pool Wildcat 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 80' Conductor 514' Surface 2205' 9903'MD 9903'TVD 2256'MD 2256'TVD Size 30" 20" I 3 -3/8" Production 9895' 9-5/8" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) feet feet feet feet Packers and SSSV (type and measured depth) None None Plugs (measured) ClBP ~ 2256'(100 sx Class G on Junklmeasured~EZ~, BP @ 9066'(100 sx Class C on None 12.Attachments Cemented Measured depth True Vertical depth 240 sx Fondu 95'MD 95'TVD 1290 sx Fondu 518'MD 518'TVD 1216 sx Fondu & 2206'MD 2206'TVD 1000 sx Class G 1300 sx Class G & 9895'MD 9895'TVD 680 sx Fondu Description summary of proposal ~ Detailed operations program - BOP sketch 13. Estimated date for commencing operation AugUst, 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 ..,.,&/~/~~"~"Y-"---~l~Jl'/]"ll" Title As sec ia te Engineer Signed ~/ Commission Use Only (JG) $A/165 Date Conditions of approval Notify commission so representative may witness ! Approva, No...~'---~ 7 Plug integrity ~ BOP Test ~ Location clearance A roved b '~v ,~;~,:~ ~.. Form 10-403 Rev 12-1-85 '~ Commissioner by order of the commission Date //-/ op) Top) Submit in triplicate APPLICATION FOR SUNDRY APPROVALS PUT RIVER STATE NO. I ARCO Alaska, Inc., requests an extension of "suspended" status for the Put River State No. 1 well. This well is scheduled for abandonment in 1987. ARCO Alaska, Inc., also requests an exception to the surface plug requirements of 20AAC25.110(c) until the well can be abandoned. The perforated intervals are isolated by cement and cement retainers. The well has kill-weight fluid between plugs and a non-freezing fluid in the annulus and the production casing above the top plug. A!aska Oil & Gas Cons, C~, Anchorage SA/165a:dmr 11 -1 0-86 MEMORAIV' )UM THRU: FROM: Stat ' of Alaska C. V. Chat~e~fij DATE:September 26, 1986 Chairman F~ LE NO.: D. EWS. 61 Lonnie C. Smith JiT~..:i'~'~- TELEPHONE NO.: Commissioner SUBJECT: Location Inspection ARCO Put River State Edgar W. Sipple, Jr. (7-10-14) Petroleum Inspector Permit No. 69-36 Sec. 7, T10N, R14E, UM Exploratory Thursday, September 4,, 1986: I traveled this date with ARCO representatiVe Mike winfree to ARCO Put River State ~1 to inspect the suspended well and location cleanup. The location was clean and contoured. The well sign was unacceptable. Photographs attached to this report verify the above conditions. I filled out an AOGCC Suspended Well and Location Report which is attached. In summary, I recommend that the Commission not approve this location until the above discrepancies are taken care of. At tachments !-001 A(Rev 10-84) Suspended Well and Location 20 AAC '25, ARTICLE 2 Report FILE INFORMATION: Operator . ~i(~ _- _ Address ~-~ t o ~ 3~ ~CL Surface Location of Well F Sec. '? , T~~,- R~_~ , U~ M. Date Suspended Permit No. ~4~ F ~.~ L API No. 50_-DI.q- Unit or Lease Name ~-~{~{&=:%'~'7~.~7-/~-.~ Well No. =_3 Field & Pool ~LD~ Condition of Pits Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard Attached to ~'~% " Information correct Yes No /~? Cellar- Yes Rat Hole Opened Fi 1 led Covered WaterWell - Plugged off Capped Open No Filled No No Covered No , Exp la na ti on Photographs taken to verify abOve condi tion~S/::::~<~§'"'> No Explanaton Work to be done to be acceptable This well'and location is (acceptable) suspended .for the period of Inspected by Da te: ~ (~8ac_ce, p..tab, le) to be classified' as thru "' 19 . . ~evised 8~24/82 E:IT. ~§/_ 'ON 0 '¥'~'n Nt Telecopy No. (907) 276-7542 August 22, 1986 Mr~ Randy Ruedrich Drilling Manager ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Suspended Well Location Inspections NW Eileen State No. 1 Sag Delta BP 31-11-16 Put River State No. 1 ~ Exxon Tract Well 19-11-15 W. Mikkelsen State No. 1 Kup River State No. 1 W. Sak River State No. 1 KRU W. Sak SWPT No. 1 W. Sak River State No. 2 Dear Mr. Ruedrich: Per our telephone conversation with Mike Winfree on August 22, 1986, we are requesting a schedule for this summer when our inspectors can accompany your representatives to the above referenced well sites for suspended well location inspections, If you have any questions, please call Harold J. Hedlund at 279-1433. Sincerely, (..."' . / Lonnie C. Smith Commis s ioner jo/A.HJH.26 June 26, 1979 Mr. Robert A. Ballog Union Oil Company of California 2323 Knoll Drive Ventura, California 93003 Re: Preparation of thin sections and paleontologic slides from public well sample library Dear Bob: Receipt is ack.nowledged for the respective thin sections, palynological slides,~ foraminiferal~slides and residues prepared from samples and cores of the following wells in fulfillment of the February 28, 1979 and April 19, 1979 letters of understanding to you and the April 30, 1979 letter to Dick Stewart: ARCO Sag River #1 ARCO Prudhoe Bay St. #1 B.P. Sag Delta #31-10-16 Shell Lake 79 Fed. #1 Sohio J-1 (9-11-13) ARCO Put River #1 (7-10-14) Mobil Gwydyr Bay S. #1 (8-12-13) Mobil W. Kuparuk Riv. #3-11-11 Mobil Kadler St. #1 (15-9-16) Exxon Canning River Unit #A-1 (19-4-24) B.P. Niakuk #2 (23-12-15) Two sets of the thin sections and palynological slides were received, as per our agreen~nt. It is presumed that inasmuch as no thin sections from the ARCO Put River #I were received, the approximate 20' of Lisburne carborate penetrated within the 9810' - 9903' interval that you sampled was considered insufficient to warrant preparation of a thin section. The slides and thin sections have now been placed in the State's public library of specially prepared well materials. A copy of the June I, 1979 inventory of special materials is enclosed for your reference. Please refer to the June and July issues of the Commission's Bulletin for additions to this inventory. Robert A. Ballog Your pro, pt preparation and return of the naterials prior to our agreed 7/1/79 date reflects well on your, Jim Hillerts, Bill Reayts, and Dick Ste~art*s attitude of fairness to others in the geologic profession and contributes to the mutual beneficial aspects of the slide preparation prograa. We look for~.ard to the possibility of ~aking additional slide preparation agreemants vith Union in the /uture. ~incerely, t~illiam Van Alert Petroleum Geolol~ist cc~ Ja~es A. Hiller, Union, Brea, CA William G. Reay, Union, Ventura, CA John A. Packard, Union, Anchors§e, AK Richard L. Stewart, Union, Anchorage,AK June 4, 1979 Er. Jm~es A. Miller UnionRese&rch Center P.O. Box 76 Brea, California 92621 Dear Jim: Here's the transmittal acknowledging receipt of the thin sections you sent ~ay 17, 1979, They all arrived in sood shape and supplement the ones you hand-delivered H~ay 14o Thin sections still to be received are both sets from the Arco Put River ti (7-10-14) and the second set from the F592D, D$71D and D266D / William Van Alen Petroleum Geolostst Union Oil Company,' .... California Union Research Ce~',. .Jr P. O. Box 76, Brea, California 92621 Telephone (714) 528-7201 E&PE-79-237 M~y 17, 1979 Mr. William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill' TRANSbIITTAL OF LISBURNE THIN SECTIONS Enclosed is one of two sets of thin sections from well cuttings for the following wells: BP-Sag Delta #31-10-16 (F593 D) ~2,105-12,390 (3 sections) BP Put River #9-11-13 (F592 D) 9,350-10,995 (18 sections) ARCO Sag River #1 (D871 D) ~,210-11/~300 (21 sections) ARCO .Prudhoe Bay St. #1 (D266 D) 8,810-10,500 (17 sections) Also enclosed is a set of seven (7) thin sections of core chips from ARCOfrom Prudhoethe coreBaYchips.St' #1 well. Only one (1) set of thin sectionsl;i'w~s"~n~d;e~~,. -. .. Core chip thin ,sections: ./8.852-61 8967-70 " 0ss-s6 '~262-68 9801-13 ~9863-68 ~,{~sk~. ' cording to Bill Reay (Ventura) this completes the carbonate (Lisburne) thin I sections from the first group of samples. If you have any questions, please Sincerely yours, ~call me. JAH' ds Please acknowledge receipt by signing and returning one copy of this letter. ler Received. ,q~/ f~'f~ .... LL.,I LLI Z lO00 2O0O 3000 4000 50000 I0 20 30 40 50 ' 60 7( TEMPERATURE -OF February 28, 1979 Mr. Robert Ballog Union Oil Company of California 2323 Knoll Drive Ventura, California 93003 Re: Acquisition of Drill Cuttings and Core Chips for Preparation of Thin Sections and Paleontologic Slides Dear~'Bob: .~ In response to our February 26, 1979 discussion, permission is hereby granted to Union Oil Company to make small quantity cuts (approximately one cc maximum each) from the State's set of samples and cores of the following wells for the purpose of preparing thin sections, palynologic slides and foraminiferal slides, subject to the below-indicated condi- tions~ Sample Set # 192 182 235 237 230 213 Fo ram ~4ell Thin Sections Palyn. Slides Slides Arco Sag River Pl (Sel. Carbonate Intrvls) Arco P.B. St. #I " " " B.P. Sag Delta 31-10-16 " " " Shell Lk. 79 Fed #1 " " " Sohio J-1 (09-11-13) " " " Arco Put River ~1 ~ " " " 8,400-12,942 (None) 8,100-12,005 " 9,100-13,877 " 10,400-15,540 " 9,100-11,871 " 2,230- 9,903 2,230- 9,903 It is understood that the cuts are to be made only from the 'relatively larger sized quantities of materials (those in excess of approximately lOcc.) and that Union will provide the State with a list of the specific sample and core footages sampled. Union shall assume all costs entailed and will provide the Alaska Oil and Gas Conservation Commission with two complete sets of all thin sections and slides prepared and return all remaining sample and core residues. We understand that it is your plan to return one complete set of the slides by May 1, 1979 and the other set by July 1, 1979, Union Oil Company of Califoruia February 28, 1979 It is a pleasure to work with you in this mutually beneficial endeavor and look forward to your company's continuous exercise of care and good Judgement in'your handling of this well material, as evidenced in the. previous sample processing arrangements you have undertaken with the State. Very truly yours, William Van Alen Petroleum Geologist .. Well Location Inspection. July ll, t972. ARCO-Put River State '[here is a gravel mound around the wellhead obscuring it from vie~,~ and an abandonment marker is sticking out of the gravel pad.. This was done prior to the big September 1969 lease sate for purposes of secreqy, The location is clean and the gravel pad is 'level, Pilings were used under the rig, and were cut flush with the pad,. The pad is rough, but clean, e.xcept for one barrel which is mostly buried, This pad was used as a revegetation test area, The exposed barrel in the reserve pit should be buried,_. ~~ bu~ ~t ~p. ! ,can ~d no reco~ ceupe~ ,~ THE UNIVERSITY OF MICHIGAN DEPARTMENT OF CHEMICAL AND METALLURGICAL ENGINEERING ANN ARBOR, MICHIGAN August 13, 1970 Mr. Harry W. Kugler Petroleum Geologist Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Kugler: It was good of you to send the information in your letter of June 10 concerning the artic north slope area of Alaska. Although I was disappointed at the time not to find any deeper temperatures, I iproceeded to write the paper and G~ closing the figure showing the temperature gradient super- imposed with the gas hydrate formation curves. Pre-prints will be available at the time of the SPE meeting in Houston. I noted the release of the information on the Prudhoe Bay well by Atlantic Richfield but they gave no tempera- tures in the ~il and ~as journal article. I am wondering whether temperatures were available anywhere in the well with some indication of the time taken as compared to the recent cementing or drilling operations. If such tempera- tures are available I would appreciate ree'eiving such information and I would recalculate the curve before the SPE meeting occurs. Likewise, any information on gas gravities or salinity of waters at given depths would be helpful. Sincerely yours, Donald L. Katz A.H. White University Professor of Chemical Engineering DLK: jli t ;NTERNAL CORRESPONDENCE Mr. D. E. Jessup Sub ject' ARCO-HORCO Well Elevations Prudhoe Bay Area Arctic Slope, Alaska From: W. C. Penttila Date: September 17, 1969 ¥~. Pat Patterson with Humble Oil & Refining, and Mr. C. B. Thomas with ARCO, both surveyors, obtained the following well elevations: Gravel Deck Braden Kelly Rig Well Name and Location______,.Pad Floor ~ ~Head_ ~ushing Lg~fland Bros. Prudhoe Bay State #1 Sec. 10, TllN-RlhE 25.0 26.0 26.5 21.0 Delta State #1 Sec. 10, T10N-R16E 20,5 21.2 -- 36. l~ Lake State #1 Sec. 2h, T10N-R15E ~o~an Rig #35 Put River State #1 Sec. 7, T10N-RlhE Southeast Eileen St. #1 Sec. 35, TllN-R12E 36.2 36.8 -- 51.8 · 39.2 ..... ; . h7.9 28.7 27.8 70.2 79.2 Rowan Rig #34 NW Eileen State #1 Sec. 28, T12N-RllE 37.8 -- 38.8 68.6 Nabors Rig #9 Sag River State #1 Sec. 2, T10N-R15E 39.0 -- 39.2 58.0 - Kup River State #1 Sec. 21, T12N-R13E 7.9 8.3 26.8 Brinkerhoff '#h2-H Toolik Federal #2 Sec. 5, T8N-R12E 121.5 .... (This well elevation was obtained by altimeter) 3.33.5 (+~') Carl B. King Drlg. Co. Rig C-1 Point Storkersen Sec. 7, T12N-R12E 25'.0 (+.l,) These elevations were obtained by differential leveling (exeept for Toolik Federal #2) .and should be accurate within +-0.5 feet. .,.,I .). ;, . Wo C. Penttila WCP:aba cc: Mr. Rex Smith - H~_O, Los Angeles Mr- Harry Kugler - Div of Oil & Gas, State of.Alaska 0 ! - 222 ~ P~EA$~ CONFIN~ EACH ~E'KTER TO ON~ DIVISION OF O!/AND GAS ANCHORAGE AtlanticRichfieldCompany North Amer~' "?- '~clucing Division Alaska Dist~,. ~ Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 279 1411 CONFIDENTIAL August 14, 1969 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attention Mr. Homer Burrell Gen tl emen' SUBJECT' Put River State #1 (7-10-14) - Section 7, TION, R14E, UM Permit No. 69-36 Enclosed is the Well'Completion Report with drilling history, core descriptions, and FIT summaries attached. The formation .samples, core chips, electric logs, and mud logs were delivered to you August 6, 1969. Please acknowledge receipt of this material by signing below and returning one copy of this letter to this office. l~]Z~ry truly yours/ //"/dames D.~Ke~s er~~ ~ Senior Drilling Engineer JDK:ve Enclosures RECEIPT ACKNOWLEDGED' by Date Form P--7 SUBMIT IN DUPLI(~,. STATE OF ALASKA {See other in- , struct ions on reverse side) OIL AND GAS CONSERVATiON COMMITTEE ii I I ii I I I _ ii ii WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* a. TYPE OF WELL: ' ' ' 0IL V,'ELL WELL DRY Other Susoandad b. TYPE OF COMPLETION: ! WELL OVER EN ' D&CK 2. NAME OF OpmR&TOR ........ A t 1 an t i c Ri ch fi e 1 d C O~P a.~y P, ESVR.DIFF' E~ Other Su~n,ondod < 5. AP1 NUIVIERI~ CODE 50-029-20017 ~ ~.~ss nm~W~:T~ON ASD SEraph No. ^DL 28313 ?. IF INDIA.N, ALLO~ OR TRIBE NAME 8. UNIT, FAI~M OR LEASE NA1VIE Put River State (7-10-14) 1 10. Fr~r~ A~NrD POOL, OR V/ILDC~T ~ .... 127' TUBIi~G I:L~OI~~ '" I 28.:.PERFORATIONS OPeN TO PROD~C~ON (Interval, size and number) , ~. ' . ':~ ~ODU~ON ' :~DA~IRST P~OD~C~ON [ ~O~cTION M~THO~ (~low~,'~a~ Hft, pump~--~ize~ and t~e of:pm~,. ' . ~ ~ST P~OD , ·FLOW ~BING ]~S~G P~S~ ~ 31. DISPOSITION OF GAS (~Old, ~ed ~0~ 4el, ~ented, etc.)- ITEST WITNESSED BY N/~_ ~ :;'<, ~. LIT 0~' ATT*CHM~NTS :", ,.: .Drilling Historyj Ft..I Summary & Core Descriptionsr' ':'. 33. I ~e'~ ~ that the 'or~i~d attached information ,. complete an~:' eorreet as determined from all:available '}eeords ~ I Il' I I I I ~; ~ ~ (S;~ Instructions and S~ces [or Additio'nal Data on ReVerse Side) P.O. Box 360, Anchoral/e, Alaska 99501 4. LOC.T,O.~ or WELL (Report location cgearllt and in aooo~.~J'~{t~ d"~ S~ ~e~uirememt.)' Ii l dcat At su.~ace / ~ '." , 11. SEC., T,, R., M., (~M ~0~ ' a343' PNL & ~436' FEL off Sac 7, T]0N, R]3~?U~ At top prod. interval report~ below N/A Sec 7, T]0N, ~]4E, At total dep~ . ; , 12. P~XT ~O. . Same as at surface , ":' ~ qO 69-~ ;.5-12-69 [ 6-1q-69~ I 7-l,69 I~KB g~ above MSL" ! N/A '~ , ~ '[ ~ I , I': '~" , ' i" ' liJ TC~ D~H, ~ & TVD~9. ~LUG ~CK MD & ~D~. ~ ~LT~ ~L., .:. :: I 21. "' INTERVA'LS DRILLED"BY ~ aaa~l I_ DE~ / HOW~Y* . (, { ROTARY TOOLS I CABLE TOOLS .: /(OIBP) 2256' I N/A . ] . all [ Nohe m.~PAODUO~G ~VA~(S), b~ ~S. ~T~O~, BO~O~, ~E' (~ A~ ~) ~, . [~.'W~ ~ N/A ~' '<~. ], Yes 24.~E E~CT~C ~n OT~ ~OOS,'~N Sc~l DIL, BHC, FDC, ~DT~PML, Velocity Surveys & CBL-GRN ::: -. , ..' , [; ::'.~ ~ .CAS~G ~ (Re~ all strings set tn well) ~.., ' :: ~ 13-3/¢" I 61 h:~5;~.:~/O 12206 ll7-1/2'.,l/:i2~6sx ' INOn~ II i ' ' ' ' ' Il 9- /8 J40-4 t.s-4 /N a 9895 I]a-]/4.l,!980..sx tN:One ATLANTIC RICHFIELD COMPANY Put River State #1 (7-10-14) Sec 7, TION, R14E, UM ADL-28313 Permit #69-36 Dri 11 in..g History Drilled 39" hole w/dry bucket to 95' KB. Cmtd 30" 157.5# csg @ 95' w/240 sx Fondu cmt. Spudded @ 7:30 a.m., May 12~ 1969. Drilled 17-1/2" hole opened to 26" to 525'. Cmtd 20" 94# csg @ 518' w/1290 sx Fondu Flyash cmt. Cmt circulated. Installed 20" Hydrill. Drilled 17-1/2" hole to 2235'. Ran Velocity Survey. Ran 71 jts 13-3/8" 54.5# & 61# csg to 2206' w/float collar @ 2170' & DV collar @ 1092'. Cmtd first stage w/lO00 sx Class "G" cmt. Cmtd second stage w/lO40 sx Fondu cmt, but failed to bump plug. Cmt did not circulate. Ran 200' of 1" pipe for top job. Used 176 sx Fondu cmt & circulated cmt to surface. Landed 13-3/8" csg & installed BOP. Tstd w/lO00 psi - would not hold. Drilled DV collar. Tstd and would not hold. Set cmt retainer @ 1055'. Mixed 500 sx Fondu Flyash cmt & squeezed cmtd open DV collar @ 1092'. Pumped away 380 sx & left 120 sx in pipe w/lO00 p~i max & final pressure. Drilled out.& tstd squeeze w/lO00 psi. OK. Drilled 12-1/4" hole to 9003'. Cut 7-5/8" cores, then reamed to 12-1/4" from 9003' to 9213'. Core Interval Cored Recovered 1 9006-9040 34 27 2 9040-9092 52 51 3 9092-9131 39 39 4 ' 9131-9193 62 62 5 9193-9212 19 17-1/2 Drilled 12-1/4" hole to 9903' TD @ 8'30 p.m. 6-15-69. Ran Schlumberger DIL, BHC, FDC, HDT, PML & Velocity Survey logs. Ran FIT & 2 CST. Ran 243 its 9-5/8" 40-47# N & P csg to 9895' w/float collar @.9812' & DV collar @ 2385'. Cmtd first stage w/1300 sx Class "G" cmt & second stage w/680 sx Fondu Flyash cmt. Installed CSgKhanger.(~ Drilled cmt & DV collar & cleaned out to 9813'. Tstd w/2000 psi. . Ran Schlumberger CBL-GRN log. Poor bonding 9091'-9094'. Perforated 9092'-9093' w/4 shots/ft. Set Halliburton RTTS @ 9034'. Squeeze #1' Established feed rate of l0 cu ft/min @ 1800 psi. Stage Squeezed w/lO0 sx.O~lass "G" cmt w/3000 psi maximum & final ~pressure. Cleaned ~ out to 9895'. Tstd squeeze w/2000 psi - broke to 1100 psi & held. Perforated 9095'- 9100' (GR=DIL) w/4 shots/foot. DST #1: Halliburton hookwall packer set @ 9072' w/tailpipe to 9085'. 3/4" BHC 5000' water cushion, Tool open w/strong blow increasing to very strong blow in 1 min. WC to surface in 29 mins. Shut in tool & took 60 min SIP. Recovered 9067' fluid c/o 5000' WC & 4067' (72 bbls) test recovery - gas cut c/o 558' (10 bbls) mud & gas cut salt water & 3509' (62 bbls) clean, gas cut salt water. Salinity: (Schl Rw) 16,500]!ppm:ii.~(62.5#/cu ft) Mud filtrate 1200 ppm. CONF DENT AL Put River State #1 (7-10-14) Drilling History Page 2 Recorders' IHMP I FP FFP ISIP FSIP FHMP Inside @ 9060' 4892 2897 4420 4420 4468 4892 Outside @ 9089' 4902 3136 4454 4454 4491 4902 Set 9-5/8" Halliburton SV squeeze packer @ 9089' (GR=DIL). Squeeze #2: Perforations 9092'-9093' & 9095'-9100' Es,t, ra.,b, lished feed rate of 18 cu ft/min @ 1800 psi. Squeezed w/120 cu ft Ciass~ cmt w/3000 psi maximum & final pressure. Reversed out 35 cu ft cmt. Perforated 9082'- 9086' (GR:DIL) w/4 shots/ft. DST #2: Packer set @ 9068', - testing 9082'-9086'. 3/4" BHC, 5000' water cushion. Tool open 70 minutes w/weak, slowly increasing to medium blow. Took 130 minute shut in. Recovered 5000' WC & 528' (8.9 bbls) mud cut salt water. Salinity 2475 ppm. Recorders' IFP FFP SIP Inside 2233 2356 4430 Outsi de 2206 2327 4408 Perforated 9076'-9086' w/4 shots/ft. DST #3' Packer set @ 9065', tstg 9076'-9086' 3/4" BHC,~.3000' rater cushion. TO~l open w/weak blow, increasing to strong biow in 15 minutes. Continued for 2 hrs 45 mins. Took 360 min SIP. Gas to surface 15 minutes after tool closed. Reversed out 54 bbls water cushion & 41 bbls oil-water emulsion - heavy black oil. Salinity (btm sample) 18,150 ppm NaCl.. Recorders' IFP FFP SIP Inside 1382 3066 4444 Outs i de 1439 3112 4454 Set EZ drill plug @ 9066'. Plug #1' Spotted 100 sx Class "G" cmt on top of EZ drill plug. Set EZ drill plug @ 2256'. Plug #2' Spotted 100 sx Class "G" cmt on top of EZ drill plug. Displaced drilling mud w/water & water w/diesel fuel. Installed blind flange on 12" Bradenhead. Released Rig @ 2'00 p.m. 7-1-69 Wel 1 suspended. CONFIDENTIAL ATLANTIC RICHFIELD COMPANY Put River State #1 (7-10-14) Sec 7, T1ON, R14E, UM ADL- 28313 Permit #69-36 FORMATION TESTS FIT #1: Test depth 8910'; sampling pressure = 200 psi; sampling time = 15 min. Final shut in pressure = 4100 psi. Shut in time = 8 min. Final hydrostatic pressure : 4850 psi. Recovered 2.2 cu ft of gas and 3400cc of mud. CONVENTIONAL CORES Core No. 1 9006' to 9040' Cut 34' Rec 27' 80% Core No. 2 9040' to 9092' Cut 52' Rec 51.2' 99% Core No. 3 9092' to 9130.6' Cut 38.6' Rec 38.6' 100% Core No. 4 9131' to 9193' Cut 62' Rec 62' 100% Core No. 5 9193' to 9212' Cut 19' Rec 17.5' 92% Total Cut 205.6' Recovered 196.3' 95% Recovery Sandstone Sandstone Sands tone Sandstone & Conglomerate Conglomerate & Sandstone SIDEWALL CORES 34 sidewall cores were taken in the interval 7300' to 9880'. 25 sidewall cores were recOVered. No sidewall cores had oil shows. No sidewall cores had gas shows. Shows: (Mud and Sample Shows) 6230' to 7505' - Baroid 8885' to 8910' - Baroid 8990' to 9590' - Baroid Conventional Cores with Oil and Gas Shows: PorositS of Cores Core No. 1 Core No. 2 Core No. 3 Core No. 4 Core No. 5 22.5% 23.1% 20.3% 22.0% 20.2% Core depths and lithology are tabulated above. CONFIDEN TIAL 6-22-69 6-26-69 IH ISI IF FF FSI FH ~27~69 6-28-69 ARCO Put River State No. 1 Set 9 5/8" @ 9895' Perf. 9092 & Sq. for water shut off. Cmf. Bond Log showed inadequate Bond @ Water Level Set 9 5/8" ret. @ 90~4. Sq. Perf. @ 9034, DST No. 1 9095-9100. 5000' WC' 3/4" BHC Tool op. w/strong blow incr. to very strong blow in one minute - remained very strong through test. Rec. 4067' (72bbl.) Net Rise 558' (10 Bbl.) GC Mud & GC SW 3509' (62 Bbl.) Salt wtr. Rw = 16;500 ppm Nacl. Inside (9060) Outs'ide (9081) 4892 '4902 4220 " 4454 2897 3136 4420 4454 4468 4491 4892 4902 DST #2 9082-86 Pkr. @ 9068 5000' WC Tool op 70 min. SI 2 hrs. & 10 min. Very weak blw - incr. steadily to med. blw. Rec: 520' Muddy Salt Water 2475 ppm Nacl. IF 2233; FF 2356; SI 4430 Forest Baker says filtrate Lee W. says good cement job. DST #3 9076-86 3000' WC Pkr. @ 9065' Tool open w/weak blow - incr. to strong blow in 15 minutes, remained strong during test - tool op 3 hrs. SI 6 hours. ARCO Put River State No. 1 (Continued) 6-28-69 DST #3 - Continued ' · · Rec. 41'Bbls. very heavy oil & water emulsion - bunch -of gunk. IF 1439 FF 3112 SI 4454 6-30-69 Top Sample Mid Sample Bottom Sample Set Plug @ 2266' 800 ppm C1 8500 ppm cl 11000 ppmcl 1320 Nacl 14025 Nacl 18150 Nacl .Released Rig @ ~4:00 P.M. 7-8-69 Girar. 12.8°API 80% Water. o, oONFIDENTIAL ~ntic Ri~¢hfieldCom pany ~laska ~District Dat~_ FORNATION TEST REPORT · Operator & Well Name~"1 ~) ' · Location II~T ~L-~ Formation Tested InterVal Tested,, qO~~''' to, ~tfO0 iC~'t).. .... Nater Cushion (we) ~ ' ~/+tf Bottom Hole Choke (BItC)~_ _ Packer set @ rail Pipe @ Opened Tool @ · Kook Hr. Min, Initial Shut In (ISI), 'Reopened Tool @ rater Cushion to Surface (WCTS) Hr. for Min. Initial Flow(IF) Min. Mud to Surface (MTS) Hr. Min. IdS to Surface (GTS) Hr. Min. Oil to Surface (OTS) Hr. Min.' ~ter to Surface (WTS) )escription of Test~ ulled Packer Loose @ _ otai ~luid produced Hr. Min. ' ':/ ': ' "-' ' .-'.. "'~-':':,? '.. ~:z~P~:'='-.': . -< ' ' .., ~. .. :...-, C . .. , ,, . . .~. . .. . . ,*., ...; ;:;.,/., ;. . . .., .. ¢... . _ ', .- . . : . -.,- . .~ ..; .. . / with ....... 1, , , , , ,ee r, .. . # Net Pull. se of: ecorded Pressures: IH Inside Recorder: ~~ O%~tside Recorder: ~.O ~ qo~ I °F. · IS I IF FF ~z.zo 2~77' YVzo FSI El CONFIDENTIAL .FLUID ,SAMPLER DA Dote 6-25-69 Number 080962 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job ~OOK,, WAISt' District. ANCHORAGE .... ~' CC. Oil · cc. Water 'Tester NH. BOA~L~ Witness , ,,,' .... cc. Mud Drilling Tot. Liquid cc. Contractor '-, ])R , S iGrovity. 'APl @ °F. ,,EoUIPMENT & I]'IOLE DATA IGas/Oil Ratio cu. ft./bbl. Formation Tested .............. - .......... t Elevation ' Ft. RESISTIVITY CHLORIDE Net Productive Interval 9072'-9085~ f:our Shots pe_~t.J cot:. CONTENT Ali Depths Measured From ' ,, ' ........ Recovery Water ~ @ ~ °F. .ppm Total Depth, ., ' ....... Ft. Recovery Mud ~ @ ' °F. Main Hole/Casing Sized ' ...... ~Recovery Mud Filtrate ~ @ ~ °F. ° ppm Drill Collar Length ' I.D.. Mud Pit Sample ~ @ ~ °F. Drill Pipe Length ' I.D .. 9072 Ft. Mud Pit Sample Filtrate ~ @ ~ "F. ppm Packer Depth(s) ....... .Mud Weight , vis _cp Depth Tester Valve - , ., ,,, , ..... Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Water 5000! Ft. Pres. Valve ,, "' Choke ..... - ......... Choke.,,3/4" .... · ,. Recovered 5000 Feetof water cushion ~' Recovered 558 , ,, F.e, etof mud' and ,gas cut salt wot:er ...... . 3 Recovered-3509 Feetof clean, gas cut salt water, sativty (Schl Rio) of 16500 PPM ~ Recovered Feetof (625 lbs/cu, feet, mud filit:rate 1200 PPM. ~ - . R,,ec0ve?d. Feet of ,. , Re~0rks Opened tool 26 minute flow..., with . a strong bl0w. increasi..ng to a very ..strong blow in 1 m...i, nute., ~ater cushion to surf.a...ce in 291minutes. *Closed tool for · . , 6~3 .minute final clOsed in pressure. ., ...... · · har ind' a e au e ' . ostatic pressure recording,._ Gauge No. 753 Gouge No. 489 Gauge NO.' ' TEMPERATURE TIME Depthi 9060 Et,._,, Depth: ........ 9081 F.t.; ,,Depth: ..... Ft. ..,, , , Calc. 24 Hour Clock 24 Hour Clock Hour Cloc.k_ Tool A.'A. _Est. ~ c)O °F. '"' Blanked Off NO Blanked Off Yes .... "Blanked Off Opened , P.,M. , Tool A.M. Actual °F; Pressures Pressures Pressures Closed P.M. Field Office Field Office Field Office Reported 'ComP~fed ..... In.__itioI Hydrostatic [4892 * ?" 4902 W ? .. Minutes ,,Minutes - , Initial 2897 2613 3136 2698 ,,, .'" ~ '" Flow ~ Final 4420 4278 4454 4314 29? !. 26 Closed. in 4420 4469 ..4454 4500 ... 60 63 .~ Initial j,, ~ .... ~.o Flow ~ ~ Final Closed in ~]' Flow Initial , ' ' :~. -- . Final ...... Closed in Fi~nol Hydrostatic /+892* '? .... 49'02* ? ..... ' ' Calc * TEST DATA CONFIDENTIAg i ~ ,-,-,, ~ '~ ~ I..d I~ O0 NOMENCLATURE b --- ApprOximate Radius of Investigation ........................ Feet ~3~ -- Approximate Radius of Investigation (Net Pay zone hi) ......... Feet D.R.-- Damage Ratio ........ - ..... ............................. El - Elevation ....... '. ..... · ........... .... - ............... -... Feet GD -- B.T. Gauge D. epth (From Surface Reference) .~ ............... ... Feet h - Interval l~ested ....... .................................. Feet - h, -- Net-Pay Thickness ....................................... Feet K -- 'Permeability ................ ....": ....................... md K, ___ Permeability (From Net Pay Zone h,i ........................ md m -- Slope Extrapolated Pressure Plot (Psi2/cycle Gas) .............. psi/cycle OF~ --Maximum Indicated Flow Rate ......................... '...MCF/D . OF2--Minimum Indicated Flow Rate ............................ MCF/D~ OF3 -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF,~ -- Tl~eoretlcal Open Flow Potential with/Damage Removed Min ..... MCF/D P s --- Extrapolated Static Pressure ............................... Psig. P F -- Final Flow Pressure ...................................... Psig. Pot -- Potentiometric Surface (Fresh Water' ) ...................... Feet e -- Average Adjusted Production Rate During Test ................ bbls/day et = Theoretical Production w/Damage Removed .................. bbls/day Q g -- Measured Gas Production Rate ............................ MCF/D R -- Corrected Recovery ...................................... bbls r,. -- Radius of Well Bore ...................................... Feet t .-- Flow Time ............................................. Minutes t ~ ___ Total Flow Time ......................................... Minutes T -- Temperature Rankine .................................... °R Z -- Compressibility Factor ............ ' ........................ . ~ -- Viscosity Gas or Liquid ................................... CP Log -- Common Log · PofenHometrlc Surface Reference to Rotary Table When Elevation NOt Given, Fresh Water Corrected to I00° F. CONFIDENTIAL Z Z © · Each Horizontal Line Equal to 1000 p.s.i. CONFIDENT'" "I_ I~nticRi'chfieldCompany AllaSka '~)i s t r ict '~ FOI%MATION TEST REPORT Operator &Well Name. · . Location DST # ~ Formation Tested Water Cushion' (WC) 5g~O O Tail Pipe @ Bottom Hole Choke (BHC) opened Tool @ Took ~Hr. /~ Min. Initial Shut In (ISI), Reopened Tool @ Water Cushion to Surface (WCTS) -. Packer set @ for ?~ Min. Initial Flow(IF) · Hr. Min. Mud to Surface (MTS) Hr. Min. Gas to Surface (GTS) Hr. Min. Oil to Surface (OTS) Hr. Min.- · ' .- ., - - , ' ' '.L' ' ,: ' - ': :- Waterto Surface (WTS) Hr. Min. ' .... ':~,".~:~ -,/"' :.,"~.:;i-']'~"'" ::" ' .... Oeseription of Tes~: - '.' ' ~ . , . -2.. ' './ -' ' ;, feet net rise of' "' · ~..~.:' ;~. ...~ . :~:~ ..... ~ ~:.~;{ '-~:"~ · . ~ ' , IS I IF ~ FSI ~ ',~ ,, . ~, :, - .,: ..... .,:, ..,;-, ,..' -, .;-,,...,{... . ::.:, ..,;,~....:,}.~.,.:,.:~( ,.:,.,.. ' , '" :' /" "~ ' "' , .~.,-' .:t' ), ' ' · , . . .. ,.,-. . , . . ulled Packer Loose @ · otal fluid produced ecorded Pressures: Inside Recorder: ~tside R~ccrdcr~ IH ,Il. T. FLUID SAMPLER DATA .. Date 6-26-69 Number NO NUMBER ' o_ SamiJler Pressure P.S.I.G. at Surface Kind Halliburton TEST ~:'. Recovery: Cu. Ft. Gas of Job HOOK WALL District AN.C~ORAGE cc. Oil cc. Water Tester C.H. BOA'~ Witness -- cc. Mud Drilling Tot. Liquid cc. .Contractor -- . ................... sm., S · Gravity. ' APl @ 'F. EQ~J I PMENT & HOLE DATA ...... Gas/Oil Ratio cu. ft./bbl. Formation Tested - .... Elevation 7/ // Ft. m I RESISTIVITY CHLORIDE Net Productive Interval. 9082-'9086' (4 shot s per ') Ft. CONTENT _ m All Depths Measured From m Recovery Water ~ @ JF .... ppm Total Depth - Ft. Recovery Mud ~ @ ~ °F, · Main Hole/Casing Size. ' ... Recovery Mud Filtrate __ @ __ °F. ppm Drill Collar Length ' I.D Mud Pit Sample __ @ __ °F. Drill Pipe Length .... ' I.D Mud Pit Sample Filtrate @ °F ..... ppm PackerDepth(s) 9068' ~ ~ , Ft. Mud Weight vis cp Depth Tester Valve 0 Ft. ,, TYPE AMOUNT Depth Back Surface Bottom . Cushion water 5000 'Ft. Pres. Valve Choke - Cho~e~/4' .. Recovered 5000 Feet of war t~.r cushion ~: j...Recovered 528 Feetofmud cut salt water - 8.9. lb./ Ral, and 2475 PPM Chlorides ~ Recovered Feet of ~' H < Recovered Feet of : ,, · O~ Recovered Feet of , .I Remarks Tool' opened for a 69 minute flow with weak,., slowly increasing to medium blow. Closed fac a 131....minute closed in pre~sure, . .. · (Gauges overpr~ssured durin~ the recording of hydrostatic prm.~.~t,.rm... Therefore no hydrostatic-readings.) ............ .... Gauge No. 753 Gauge No. 489 Gauge No. TEMPERATURE TIME Depth: '.. Ft. .....Depth: - . Ft. Depth: Ft. 24 Hour Clock 24 Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off no Blanked Off ~Tes. .... Blanked Off ...... Opened P.M. Tool A.M. Actual .... °F. Pressures Pressures ....... Pr,,essures Closed P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic ' * - ~ 'Minutes Minutes ........ Initial 2206 2207 2233 2233 ._.~ Flow u-~..,, Final 2356 2334 2356 2355, 70 69 Closed in 4430 4423 44~'0 4440 ........ 130 131 '~ Initial ....... ._ Flow Final ..... ~' Closed in - - . ........- - _ Initiol ............. !~o Flow "' - - I~'~ Final .... Closed in .... ,,, Final Hydrostatic - * - * - - _ ffRINT[D IN TEST DATA CO NTF, rD.E. .r FORMATION "(..! · ~: § 0 . ,-, ~-o-u~om~o® .~.~ o~ ~ ~ o ~ ~' ,o ...... ~" ........ , _ ~ Z ~ ~ Z ~ ...... o ............. ~ "' ~ ~ ,, , , 0 o C :~ m~ 0 c 'n~ ~ O' ........ -- ,,, ,, ,, , .... ~:~ o , ...... ,, ~ , , ,, NOMENCLATURE b ~ Approximate Radius of Investigation'. ....................... Feet ,. J3~ -- Approximate Radius of Investigation (Net'Pay Zone h~) 'Fe~t D.R.-- Damage Ratio ............................................ El - Elevation ................................................. Feet .GD -'- B.T. Gauge Depth (From Surface Re~erence) ................... Feet · h -- Interval Tested ......................................... Feet. h ~ -- Net Pay Thickness ....................................... Feet K ' Permeability ........................................... md K~ ---Permeability (From Net Pay Zone h~) ........................ md m -- Slope Extrapolated Pressure Plot (PsiS/cycle Gas) .............. psi/cycle OF~ ~---Maximum Indicated Flow Rate ............................ MCF/D OF~-'- Minimum Indicated Flow Rate ............................ MCF/D OFa -- Theoretical Open Flow Potential with/Damage Removed Max ...... MCF/D OF4 '-- Theoretical Open Flow Potential with/Damage Removed-Min ..... MCF/D Ps -- ExtraPolated Static Pressure ............................... Psig. p~ _ Final Flow Pressure ' Psig. p o, -- Potentiometric Surface (Fresh Water ~) ...................... Feet e -- Average Adjusted Production Rate During Test ................ bbls/day Q, -- Theoretical Production w/Damage Removed .................. bbls/day e~ --Measured Gas Production Rate ............................ MCF/D R -- Corrected Recovery ' bbls r,~ -- Radius of Well Bore ...................................... Feet t --- Flow Time ............................................. Minutes -- Total Flow Time ......................................... Minutes to T = Temperature Rankine .................................... °R Z -- Compressibility Factor ..................................... ~lJ --' Viscosity Gas or Liquid ................................... CP Log -- Common Log * Pofenfiomefr~c Surface Refe.~e~ce to R. ofary Table When Elevation Not Given, Fresh Woter Correctecl to 100: F. CONFIDENTIAL Each Horizontal Line Equal to 1000 p.s.i. ~nticRichfie~Company {laska'District FORMATION TEST REPORT Location ~ST # ~3 Formation Tested Interval Tested to fD~ Hater Cushion (WC) rail Pipe @ 0 Bottom Hole Choke. (BHC). ~/~ · · Opened Tool @ Packer set @ for B ~/2~ Min. Initial Flow(IF) rook Hr. ~ater Cushion to Surface (WCTS)' Sas to Surface (GTS) Hr. Nater to Surface (WTS) Hr. )escription of Test: Min. Initial Shut In (ISI), Reopened Tool @- .. Hr. Min. Mud to Surface (MTS) ·. Min. Oil to Surface (OTS) Hr. , , . _ Hr. Min. Min.' 3 ~llled Packer Loose @ :ecovered PM with !otal fluid produced ;ecorded Pressures: Inside Recorder: Outside Recorder: ISI # Net Pull, f~et net rise of: · . : . BW! FSI M~DE Ff~ US~l~ . __ "ToP TOOL ~-~ ' MI~~. GAB AT b~tFACE MJ]tt~E8. .' ~0~1 . ' ~ ...... '- ~ ' - - '"/'. ..... "':-' ":'4~": (Give ~or~e ~e~t o~ -" - :_ . ~"; -- :-__ - .... _ .... __ - i 1] [i i le i ~ , ~.. ~~T .... . .... ~..' ~ .... , .... .. . -. '" "' -' 44 4 : . _ . _ ~. : . NOMENCLATURE b -- Approximate Radius of Investigation ........................ Feet J3~ -- Approximate Radius of Investigation (Net Pay Zone h~) ......... Feet D.R.-- Damage Ratio .......................................... E! - Elevation ............................................... Feet GD -- B.T. Gauge I~epth (From Surface Reference) .................. ,. Feet h -- Interval Tested ......................................... Feet h, -- Net Pay Thickness ........................................ Feet K _- Permeability ...................................... - ..... md K t -- Permeability (From Net Pay Zone h,) ........................ md m -- Slope Extrapolated Pressure Plot (Psi2/cycle Gas) .............. psi/cycle OF~ ~ Maximum Indicated Flow Rate ...................... ' ...... MCF/D OF2-- Minimum Indicated Flow Rate ............... '..~ .......... MCF/D OF:~ -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF4 '-' Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D P P~ P o, Q Q, Q~ R r~ t to T' Z s -- Extrapolated Static Pressure ......... : ..... · ........... ' ..... Psig. -- Final Flow Pressure ...................................... Psig. -- Potentiometric Surface (Fresh Water* ) ...................... Feet -- Average Adjusted Production Rate During Test .. ............... bbls/day --- Theoretical Production w/Damage Removed ....... ' ........... bbls/day --Measured Gas Production Rate ......... ~.' ................. MCF/D -- Corrected Recovery ...................................... bbls '-- Radius of Well Bore ...................................... Feet --- Flow Time .............................................. Minutes -- Total Flow Time i ........................................ Minutes . --- Temperature Rankine .................................... °R -- Compressibility Factor ...................................... ~ -- Viscosity Gas or Liquid .................................... CP Log -- Common Log ~ · .Pofenfiomefric Surface Reference to Rotary Table When [:levafion Not Given, Fresh Water Corrected to I00° F. CONFIDEt' ,!T AL TIME ............... 8 Each Horizontal Line Equal to 1000 p.s.i. _..,FLUID r - ' " ~ ' (o- ?-~ - (oC) ' [ Ticket S A M P L E R D A T A . Dote -- Number N0 NUHBER .. Sampler Pressure P.S.I.G. at Surface Kind Halliburton T1;'.ST #'3 J RecoverY: Cu. Ft. Gas of Job tiOOK WA[,[, District ANC[-[O~GE _ / cc. Oil . cc-'Water Tester iD. ti. BOATHAN Witness 9. _ ' cc. Mud Drilling Tot. Liquid cc. Contractor - . silt Gravity. '~PI @ °F. EQUIPMENT & HOLE D-^T _ Gas/Oil Ratio... cu. ft./bbl. Formation Tested - * Elevation r,,,~ t,,,'/ Ft. RESISTIVITY CHLORIDE Net Productive Interval. 9076-9086' 4 shots per ' Ft. CONTENT All Depths Measured From - Recovery Water @ °F. pp.m Total Depth - Ft. Recovery Mud -- @ 'F. ° Main Hole/Casing Size - Recovery Mud Filtrate @ °F, .ppm Drill Caller Length ' . I.D Hud Pit Sample @ . °F. Drill Pipe Length_. - I.D · ~Au~·Pit Sample Filtrate @ °F. ppm PackerDepth(s) 9065 Ft. Mud Weight vis cp Depth Tester Valve - Ft. TYPE AMOUNT .* Depth Back Surface Bottom Cushion water 3000 * Ft. Pre?. Valve Choke - Choke 3/4 · . .. Recovered 54 bbls, ~=C~f reversed out water cushion Recovered 41 bbls. Feetof reversed out oil-water emulsion--heavy black oil Recove'red Feetof Salinity of bOttom 'sample: 18,150 PPM NaC1 Recovered Feet of ' *' ~' ' ' ' .. · · , . Recovered Feet of ~ ~ * r ' ' ~' ' ' ' ' ~ ' , . , · Remarks Tool opened with a weak blow...increasing to strong blow in 15 minutes .... · continued for 2 hours and 45 minutes. Closed tool for 360 minute closed in Pressure. Gas to the surface in,R5 minutes after tool was closhd. _ *G'au~es overpressured durin~ the record~n~ o~ hvdro.~r~r~c Dres~ur~.~... ! . there fore no hydrostatic readings available.' Gauge No. 753 Gauge No. 489 Gauge No. TEMPERATURE TIME Depth: - Ft. Depth: - FL, Depth: Ft. 24 Hour Clock 24 Hour Clock ' Hour Clock Tool A.jVL E__st. °F. Blanked Off no Blanked Off ye s Blanked Off Opened P./VL Tool · A.M. A.~ctual °F. Pressures Pressures Pressures Closed P.hA. Field Office Field Office Field Office Reported Computed Initial Hydrostatic - * - ~ Minutes Minutes' '~ FI0w- Initial 1382 1368 1439 1440. . ~-~. -- Final 3066 3081 3112 3101 ]]80 - ~ Closed in 4444 4448 4454 4461 360 - i~ Flow Initial .... Final .... ._._._ Closed in - - . - - ~ Flaw Initial .... ~. -- Final .... Closed in .... F.~inal Hydrostatic - * - , '"'"""'""'"'" , FORMATION TEST DATA OON'FI'BE'N"T CORE LABORATORIES, INC. Petroleum Re~e)~t, oir Engineering DALLAS. TEXAS 75207 December 9, 1971 R~ERVOIR FLUID ANALYSIS BP Alaska Inc. P. O. Box4-1379 Anchorage, Alaska 99503 Attention: Senior Petroleum Engineer CONFIDENTIAL STATE OF ALASKA COPY Subject: Reservoir Fluid Study BP 27-11- 14 Well Prudhoe Bay Field Alaska Our File Number: RFL 7158 Gentlemen: Samples of ~ary separator liquid and vapor, second-stage separator liquid and vapor and stock tank liquid si~ were collected from the subject well during production testing at three flow rates, and. these samples were for- warded to our Dallas laboratory for use in a reservoir fluid study. Pre- sented in this report are the results of the reservoir fluid study that was performed as requested by BP Alaska Inco After correction for the factors shown on page one, the producing gas-liquid ratio during Flow Rate 1 was 27,715cubic feet of primary separator gas at' 14,696 psia and 60° Fo per barrel of stock tank liquid at 60© F. After determining the shrinkage of the primary separator liquid to stock tank conditions in our laboratory, this producing ratio was found to be equivalent to Zl, 944 standard cubic feet of primary separator gas per barrel of primary separator liquid at 1016 psig and 60© Fo This ratio was then used in conjunc- tion with the measured compositions of the primary separator products to calculate the composition of the well stream material that was produced during Rate 1, and these data are shown on page three° The producing gas-liquid ratio during Flow Rate 2 was calculated to be 28,278 cubic feet of primary separator gas at 14o 696 psia and 60° F. per 'BI~ Alaska Inc. BP 27-11-14 Well C01 F D NTIA OF ALASKA COPY Page Two barrel of stock tank liquid at 60 © F. In the laboratory this ratio was found to be equivalent to 229 750 standard cubic feet of primary separator gas per barrel of primary separator, liquid at 1015 psig and 60° F. This ratio was then used in conjunction with the measured compositions of the primary separator products to calculate the well stream composition during Rate Z and these data are shown on page six. The producing gas-liquid ratio during Rate 3 was calculated to be 28,433 cubic feet of primary separator gas per barrel of stock tank liquid at 60° F. After determining the shrinkage characteristics of the primary separator liquid to stock tank conditions, this ratio was found to be equivalent to 22,746 standard cubic feet of primary separator gas per barrel of primary separator liquid at 1020 psig and 60° F. This ratio was then used in con- junction with the measured compositions of the primary separator products to calculate the well stream composition that was produced during Rate 3, and these data are shown on page 13. A compositional analysis of the stock tank liquid collected during Rate 3 was performed in our laboratory to the undecanes plus fraction, and these data are shown on page eight. An ASTM distillation was also performed on a sample of this stock tank liquid and these results are reported on page nine. · The compositions of the secondary separator products that were collected ' during Rate 3 were determined in our laboratory and these data .are shown on pages ten and 11 of the report. The primary separator products collected during Rate 3 were then physically recombined to their producing gas-liquid ratio and the resulting mixture was used in the performance of ihe reservoir fluid study. A sample of thi.s re- combined mixture was then charged to a high-pressure visual cell and examined at the reservoir temperature of 197© F. During a constant compo- sition expansion at this temperature a retrograde dew point: was observed at 4148 psig. l~resented on page 14 are the results of the pressure-volume relations that were determined on this sample, along with the measured deviation factor at the dew point pres sure and above. CONFIDENTIAL' TATE OF ALASKA COPY BP Alaska Ind. BPZT-11-14 Well 'Page Three A .constant-volume depletion study was then performed on a sample of the reservoir fluid at 197° F. This depletion consisted of a series of expan- sions and constant pressure displacements, with each displacement ter- 'minating at the volume occupied by the reservoir gas phase at 4148 psig. The gas produced at each depletion level was charged to low temperature, fractional distillation equipment for analysis and volume measurements. The results of this depletion are tabulated on page 15 of the report. Smoothed compositions and equilibrium ratios from the literature were used to calculate the surface recoveries that may be expected as reser- voir pressure declines. These recoveries are based upgn one MMSCF of fluid in place at the dew point pressure, and they are shown on page 16. Also shown on this page, and on the same basis, are 'the total plant products available from the well stream. A plant efficiency of 100 percent has been assumed for these recovery calculations. The volumes of retrograde liquid condensation that will accumulate in the reservoir were determined at the various pressure levels during the con- stant volume depletion, and these data are shown on page 17. It has been our pleasure to perform this study for BP Alaska Inco Should you have any questions regarding the data or if we may assist you further, please do not hesitate to contact us. Very truly yours, PLM:HS:dl 7 cc. - Addressee · Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manager Company Well Field BP A'laska Inc. BP 27-11-14, Rate 1 Prudhoe Bay' CORE LA30~,ATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS Date Sampled County. State CONF!D,?NTIAL STATE OF ALASKA COPY Page, 1 of,, 24 · File RVL 71 58 . May 29, 1971 Alaska FORMATI~)N CHARACTERISTICS Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas-Liquid Ratio Production Rate Separator Pressure and Temperature Liquid Gravity at 60° F. Datum Sadlerochit Sandstone ,19 PSiO@ .Ft. .SCF/Bbl PSIG .Bbls/Day °F. °API Ft. Subsea Elevation Total Depth Producing Interval Tubing Size and Depth Open Flow Potential Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge WELL CHARACTERISTICS SAMPLING CONDITIONS Flowing Tubing Pressure (90 o Fo ) Flowing Bottom Hole Pressure Primary Separator Pressure Primary Separator Temperature Secondary Separator Pressure Secondary Separator Temperature Field Stock Tank Liquid Gravity Primary Separator Gas PrOduction Rate Pressure Base Temperature Base Compressibility Factor (F,~) Gas Gravity (Laboratory) Gas Gravity Factor (Fg) Stock Tank .Liquid Production Rate @ 60° F, Primary Separator Gas/. Stock T an k Core Laboratories, Inc., Engineer l ~,, 696 PSIA 60 o F. 1o 08:7 0.74'7 1.1 57'0 Ft. 8474-8480 .Ft In. to Ft. 8 5 MMSCF/Day 4278 PSIG @ 8413 .Ft. 197 o F.@ Ft. -Rate 1 3089 PSIG 422 3 PSIG 1016 PSIG 104 o F. _'39 PSIG 59 oF. 53° 6 avg'. o API@ 60© F. 57 3 7 MSCF/Day Z 07 Bbls/Day Liquid Ratio 2 7 ? ~l 5_ _ SCF/Bbl or 23 6.0 8 . Bbls/MMSCF REMARKS' SS SS These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use. this report is made. The interpretations or opinions expressed represent the best judl~ment of Core Laboratories, Inc. (all errors and omis, sions excepted); but Core Laboratories, Ine, and its officers and employees, assume no respons!bility and make no warranty or representations as to the productivity, proper opera- ~{,~,, .~,' ..~6f.h}on.~a aC any nil. ~,aa or other mineral ~,~et! Or saud in connec'.i,~n with which such report is ustc] or relied upon. CONFIDENTIAL CORE LABORATORIES, INC. ~ TATE OF ALASKA COPY mAI. I.AS. TEXAS Page 2 of 24 - File RFL 7158 SEPARATOR TESTS OF Well BP 27- 11 - 14, Rate 1 Primary Separator: Liquid ....... SAMPLE SEPARATOR PRESSURE, .1~! GAUGE SEPARATOR J SEPARATOR j STOCK TANK TEMPERATURE, IGAS/OIL RATIOJGAS/OIL RATIO · S. JSee Foot Note (1) See Foot Note (1) STOCK TANK GRAVITY, · AP! ~ 60· F. SHRINKAGE FACTOR 0 V,/Vs^?. See Foot ~'ote (2) JFORMATION VOLU ME FACTOR, VlAT ./VR See Foot Note (3) SPB~CIFIC GRAVITY OF FI-ABHED GAB -39 59 528 44 54.4 0. 7680 1. 302 (1) Separator and Stock Tank Gas/Oil Ratio in cubic feet of gas @ 60° Fi-and 14fl PSI absolute per barrel of stock tank oil @ 60° F. (2) Shrinkage Factor: v./vs^,, is'barrels of stock tank oil @ 60° F. per barrel of saturated oil @ 1 ..016. .. PSI gauge and 1-04 oF. (3) Formation Volume Factor: vs^?./w is barrels of saturated oil @ 1016psi gauge and 104 ? F. per barrel of stock tank oil @ 60° F. These. analyses, opinions or Interpretations are hied on observations and material supplied by the ciient to whom, and for whose exeiuslve and confidential use, this report is made. The interl)retatlo~m or opinions expressed, rel~resen[ the best judgment of Core L~boratories, ln¢, (ali errors and omissions exoepted); but C~re Laboratories. I.ne. and its officers and employees, assume no re.~t~nsibiiit~r and make no warranty or reprezentations as to the productivity, proper opera- CORE' LABORATO~iF_~, INC. Petrole#m R~ervoir Eng~neeri#g DALJ..A$. TEXAS CONF!.D?,]TIAL " OF ALASKA COPY .TTAiE Pag~_- 3 of 24 ' Fil- RFL 7158 . Well BP 27-11-14, Rate 1 Hydrocarbon Analyses of Separator Products and Calculated Wen Stream Separator Liquid Mol Per 'Cent Separator Gas Mol Per Cent GPM Well Stream Mol Per Cent GPM Carbon Dioxide Nitrogen Methane Ethane Propane ...ho-Butane n-Butane iso-Pentane ~ n-Pentane ' I-Iexanes ; Heptanes plus 6.11 11.11 0.05 O.66 21,89 78.71 5.55 5.27 5.94 2.38 1.51 0.32 4.34 O. 73 2004 O. 18 3.13 0.23 5.55 O. 18 43°89 0.23 100.00 100.00 O. 653 O. 104 O. 230 Oo 066 0,083 0.073 O. 104 10.83 0.63 75.53 5.29 2.58 0.39 0.93 0.28 0.39 0.48 2.67 100.00 O. 7O8 O. 127 0.292 O. 102 O. 141 0.195 1.430 2. 995 .Properties of Heptanes plus API gravity @ 60° F. Specific gravity @ 60/60° F. Molecular weight 48.1 0. 7879 136 103 Calculated separator gas,gravity (air -- 1.000) -- 0. 747 Calculated gross heating value for separator gas -- 10 Z 0 RTU per cubic foot of dry gas @ 14.696 psia and 60° F. Primary. separator gas collected @ 1016 psig and 104 'F. -Primary separator'liquid collected @ 10 i 6 psig and 104 'F. Primary separator gas/separator liquid ratio Primary 'separator liquid/stock tank liquid ratio Primary separator gas/well stream ratio Stock tank liquid/well stream ratio 2. 194~ SCF/Bbl @ 60° F. I. Z 63 Rbls @ 60° F./Bbl 944. i Z MSCF/MMSCF 34.07 ]{bls/MMSCF .0. 785 133 ?hese analyses, opinions or Interpretations are based on observations 'and material supplied by the client to whom. and for whom exclusive and eonfldel~Jal use, this report is made. The interpretations or _opinkg~s exprem~l represent the., .b~..t jud,gmen, t of Core Laboratories, CORE LABOi,ATORIES, INC. Petroleum Reservoir Engineering DALI.AS. TEXAS Company BP Alaska Inc. Well Field Bp27~11-14. Rate 2 Prudhoe Bay Date Sampled County state CONF'D"'NTIAL :, ::"'TATE OF ALASKA COPY Page 4' of. 24 . File, RFL 71 58 May 30,. 1971 Alaska FORMATION CHARACTERISTICS Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas-Liquid Ratio Production Rate Separator Pressure and Temperature Liquid Gravity at 60° F. Datum Elevation Total Depth Producing Interval Tubing Size and Depth Open Flow Potential Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge WELL CHARACTERISTICS SAMPLING CONDITIONS i 4o 696 PSIA 60 o F. 1. 087 0.746. 1 o 1578 Sadleroch[t Sandstone ., 19 , Flowing Tubing Pressure (96° Fo ) Flowing Bottom Hole Pressure Primary ,Separator Pressure Primary Separator Temperature Secondary Separator Pressure Secondary Separator Temperature Field Stock Tank Liquid Gravity Primary Separator Gas Production Rate Pressure Base Temperature Base Compressibility Factor (Fpv) Gas Gravity (Laboratory) Gas Gravity Factor (Fg) Stock Tank Liquid Production Rate @ 60° F, Primary Separator Gas/Stock Tank Core Laboratories, Inc., Engineer REMARKS' PSIG @ Ft. 8CF/Bbl PSIG Rbls/Day °F. Ft. Subsea 8474-8480 Ft. Tn. to ,.. Ft. ~,, 8 5 , MMSCF/Day 4278 PSIG @ 8413 Ft. , 19 , .1,97 OF.@ Ft. -Rate Z Z 974 ..... PSIG 4166 PSIG 101.5 PSIG i07 o F. 3 9 PSIG 65 OF. 530 6 argo o API@ 60© F. 8 936 MSCF/Day 316 Rbls/Day Liquid Ratio Z 8 Z'78 SCF/Bbl or 35 o 36 Bbls/MMSCF SS These analyses, opinions or interpretations are based on observations and material supplic~l by the client to whom. and for whose exclusive and confidential u~e. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); but o~.~ · .~.....,.~.:~,. t..~ ~...~ ;*o ~,;~-. ~ .~.~.~.,~..- .-~,,,.....w~ ~.~,~;h;;i~v ~n,t ma, k~ no warranty or representations as to the productivity, proper opera- BEPARATOR PRESSURE, I~1 GAUGE CORE LABORATORIES, INC. P#troleum Reservoir Engineering DALLAS, TEXAS " Tr ',:OF AL^SKA COPY Page 5 of File, RFL 7158 SEPARATOR TESTS OF 24 Well BP 27-11-14. Rate 2 Primary Separator' Liquid .... SAMPLE BEPARATOR TEMPERATURE, · F. , iSaa Foot Note (1) iSee Foot Note (1)! APl (~ 60· F* iii I FORMATION BHRINKAGE I VOL. UM~ FACTOR, I FACTOR, See Foot Note (2) ISee Foot l~ote (3) 39 65 492 42 54.4 0.7788 · 1.284 BPE~ClFIC GRAVITY OF FI. ABHIr D GAS (1) Separator and Stock Tank Gas/Oil Ratio in cubic feet of gas @ 60° F. and 14.7 PSI absolute per barrel of stock tank oil @ 60° F. (2) Shrinkage Factor: w/rs^,, isbarrels of stock tank oil @ 60° F. per barrel of saturated oil.@,_1 01 5 PSI gauge and t07 oF. (3) Fomation Volume Factor: w^,./w is barrels of saturated oil @ 1015 ,pSI gauge and 107 o F. per barrel of stock tank oil @ 60° F. These analyses, opinions.or interpretations are based on observations and material supplied by the client to whom, and roi wha~e exclusive and confidential use, this r~elOOrt is m~de. Tho 'tnterpr~tations or opinions expressed represent the best Sudlcm~ent of Core l~borfltorjes. Inc. (all errors and omissions excopted); but CORE LABORATORIF~, INC. Petro]e#~n Eeservok £#jinee~g DAL,,i.A$. TE3CAB ( rO !D mfl-IAt fTATE OF ALASKA COPY Pa~. 6 ,of 24 File RFL 7158 Well BP 27-11-14, - Rate 2 Hydrocarbon Analyses of Separator Products and .,Cale~at~ Wen Str,,eam. Separator Liquid Separator Gas Well. Str~_m Mol Per Cent Mol Per Cent GPM Mol Per Cent GPM j iL ~1 1111 ,,,, . Carbon Dioxide .. Nitro~en Methane Ethane Propane iso-Butane n-Butane iso.Pentane n-Pentane I-Iexanes Heptanes plus ,e 50 93 11.06 10o82 0.07 0.66 0.63 21.40 78.76 76.06 5.32 '5° 25 5.25 5.68 2.40 0. 659 2.55 1.71 0.31 0. 101 0.38 4.15 0.73 0. 230 00 89 2.06 0, 18 0. 066 0.27. 2.90 0.23 0o 083 0o 36 5.68 0. 19 0. 077 0.45 450 10 0.23 0o 104 2.34 '100.00 '100.00 1o 320 100.00 0. 700 0o 124 0. 280 0. 099 0o 130 0. 183 1.262 2° 778 ":Properties of HeptaneS plus API gravity @ 60° F. Specific gravity @ 60/60° F. Molecular weight 48.0 O. 7882 137 0.785 103 134 · 'Calculated separator gas gravity (air -- 1.000): 0. 746 Calcul. ated gross heating value for separator gas -- 1 0 21 BTU per cubic foot of dry gas @ 14.696 psia and 60° F. Primary separator gas collected @ 10 i 5 .psig and 107 'F. Primary separator liquid collected @ 101 5 .psig and 107 OF. Z2 7 5 0 SCF/Bbl @ 60° F. 1. Z4 3 Rbls @ 60° F./Bbl 9 5Z. 97 MSCF/MMSCF 33.70 Rbls/MMSCF Primary separator gas/separator liquid ratio Primary separator liquid/stock tank liquid ratio Primary separator gas/well s'tream ratio Stock tank iiquid/well stream ratio These analyzes, opinions or interpretations are based on observations and material supplied by the client to whom, and for who~ exclusive and confldmltial this revert is. made. The interpretations or 'opinions exoressed repre~nt the best judgment of Core Laboratories, lac. (all errors and omissions excepted); but Core Lal~..~rator~es. Inc.. and i~ officer~ and emo~oyees, assume no resoonslbility and ~nake no warranty or reVre~entations as to the l)roductivity, I)ro~r o~.ra- CORE LABOKATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS ¢ONF D,- TIAL ?ATE OF ,LASKA COPY Page 7 of. 24 File RFL 7158 · Company BP Alaska Inc. Date Sampled. Well B P 2 7 - 11 - 14, R at e 3 County Field Prudhoe Bay State May 31, 1971 Alaska FORMATION CHARACTERISTICS Formation Name Date First Well Completed Original Reservoir Pressure · Original Produced Gas-Liquid Ratio Production Rate Separator Pressure and Temperature Liquid Gravity at 60° F. Datum Elevation Total Depth Producing Interval Tubing Size and Depth Open Flow Potential Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge WELL CHARACTERISTICS SAMPLING CONDITIONS Flowing Tubing Pressure ( 10 7 Flowing Bottom Hole Pressure Primary Separator Pressure Primary Separator Temperature Secondary Separator Pressure Secondary Separator Temperature Field Stock Tank Liquid Gravity Primary Separator Gas Production Rate Pressure Base Temperature Base Compressibility Factor (F,,) Gas Gravity (Laboratory) Gas Gravity Factor Stock Tank .Liquid Production Rate ~ 60° F. Primary Separator Gas/. Stock 'Yank Liquid Ratio or Core Laboratories, Inc., Engineer REMARKS' 14.696 PSIA 60 o F. 1 o 1578 0. 746 1o087 Sadie rochit Sandstone Psio @ PSIG ., 19 Ft. SC'F/BM Rbls/Day °F. Ft. Subsea . Ft.. 8474-8480 85 4278 197 In. to. PSIG @ Ft. SS Ft. MMSCF/Day 8413 Ft. ss ,, 19 Ft. -Rate 3 2682 409.5 1020 PSIG PSIG PSIG 10q 41 °F. PSIG .70 °F. 530 6 avg. 13790 o API ~ 60° F. MSCF/Day 485 28433 35,17 Bbls/Day SCF/Bbl Rbls/MMISCF These analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for whose exclusive nnd confidential use. this report is made. '['he interpretations or opinions expressed represent the best judgment of Core I,aboratories. Inc. (all errors and omissions excepted); but Core Laborlitorids. Inc. and its officers and emp]oy~m$, asstlme Ilo responsibility and make no warranty or repr~en~tiona as ~ the pr~luctivity, proper olmra- Petroleum Reservoir Engine~ing DALLAS, T~AS Company. BP Alaska Inc. Well BP 27-11-14, Rate 3 Field Prudhoe Bay HYDROCARBON ANALYSIS OF COMPONENT MOL WEIGHT PER CENT PER CENT Formation Page 8 of 24 File RFL7158 Sadlerochit Sandstone County State Al.aska Stock Tank Liquid DENSITY ~ 60° F. GRAMS PER CUBIC CENTIMETER SAMPLE AP! 60e F. . MOLECULAR WEIGHT Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes H eptan e s Octanes Nonanes Decanes Undecanes plus 0.02 Nil 0.01 0020 1.67 0.85 4.30 3.46 4.05 11010 13012 16o 07 10.79 8o53 25.83 100o O0 0o01 Nil Trace 0.05 0.60 0040 2003 2:03 20 38 7075 9.40 14o 26 11007 9.65 400 37 100o O0 0.730 -0o757 0o775 O. 788 00 829 620 1 55.2 50o9 47.8 3900 88 10'9 126 139 192 ST^TE OF ^LAS COPY Petrolettra R~.~er~oir £ngi#,~ing · Page 9 of 24 .F~le RFL 7,,,158 Well BP 27-11-14, Rate 3 ASTM Distillation of Stock Tank Liquid S_ample Percent T e mp,,e ratur e, IBP 120 5 165 10 190 20 220 30 248 40 274 50 302 60 335 70 382 80 449 90 542 95 608 96 EP 619 Recovery 9.6, 0% Loss 0, 5% Residue 3, 5% °F, Stock tank liquid gravity = 53.9 ©API at 60 o F. These analysos, opinions or interpretations are based on ~)bservations and material supplied by the client to whom, and for who~ exclusive and confidential u~, this ~imrt is made. The interpretations or opinions expresst~ represent ~e ~st judgment of Core La~ratories, Inc. (all errors and omissions except); but Core Laboratories. Inc. and its officers and employees, assume no resi~nsibitity and make no warranty or repre~n~tio~ ~ to the pr~uctivity, proof o~ra- CONFIDENTIAL STATE OF ALASKA Petroleum Reservoir En§i~eeriag DALES. TEXAS COPY ~e 10 of, 2 ~ Company B P A la s ka In c, Formation Well BP 27-11-14, Rate 3 County Field Prudhoe Bay State HYDROCARBON ANALYSIS OF Secondary Separator File, , RFL 7158 Sadlerochit Sandstone Alaska GAS SAMPLE Carbon Dioxide 14.8 0 Nitrogen 0.16 Methane 54.93 Ethane 12.30 Propane 9 o 34 2.56:4 iso-Butane 1.56 0.509 n-Butane 3 o 66 1 ° 1 51 iso-Pentane 0 o 87 0 ° 318 n-Pentane 1.07 0.387 Hexanes 0 o 6 5 0.2 64 Heptanes plus 0.66 0.299 100.00 5.492 Calculated gas gravity ( air: 1.000) = 0. 996 Calculated gross heating value -- 1323 BTU per cubic foot of dry gas at 14.696 psia at 60° F. Collected at 41 psig and 70 o F. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and c6nfidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core I,u.boratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its ottieers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- r. lon. ar *~rofit:d}lono.~.q of any oil. ~as or o£her mineral well or sand in connection with which such rel~o~ is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS Page 11 of. 24 File RFL 7158 Company. BP Alaska Inc. Formation Well BP 27-11-14, Rate 3 County Sa, dlerochit Sand Field Prudhoe Bay State ,Alaska Secondary HYDROCARBON ANALYSIS OF Separator Liquid SAMPLE COMPONENT MOL WEIGHT [MiN$1TY (~ 60e Ir. · APl MOLECULAR PER CENT PER CENT GRAMS PER CUBIC (~ 60e P. WEIGHT CENTIMETER Carbon Dioxide 0.60 0.22 · Nitrogen T r a c e Methane 0.84 0.11 Ethane 1o 20 0.31 Propane 3.22 1.21 iso-Butane 1.41 0.7 0 n-Butane 4.70 2.32 is0-Pentane 3.06 1.88 n-Pentane 40 93 3 o 02 Hexanes 10.79 7.87 Heptanes plus 69 o 25 82.36 100o 00 100.00' STATE OF ALASKA COPY O. 7907 47.3 140 Collected at 41 psig and 70 o F. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, ~£PARATOR PRIr$$U Rir. I~1 GAUGE: CORE LABORATORIES, INC. P#troleum Re~ervoi~ Engineering DALI-AB. TEXA$ Page 12 of. 24 Pile RFL 7158 Well - Primary · SEPARATOR TESTS OF S, eparato, r Liquid BP 27-11-14, Rate 3 SAMPLE $IrPARATOR ]SIr.ARA'FOR S STOCK TANK TIrMF'IrRATURIr, GAS/Gl/ RATIO I GAS/OIL. RATIO ' F. I See Foot Note (1) [See Foot Note (1) STOCK TANK GRAVITY, · APl ~} 60· F. FORMATION SHRINKAGE VOLUME FACTOR, FACTOR, V~/Vs^v. V,^T./V. See Foot Note (2) See Foot N<~te (3) 41 70 526 43 54.3 0. 7728 1. 294 SPECIFIC GRAVITY OF FLASHED GAS CONF!D"NTIAL STATE OF ALASKA COPY (1) Separator and Stock Tank Gas/Oil Ratio in cubic feet o~f gas @ 60° F. and 14.7 PSI absolute per barrel of stock tank oil @ 60° F. (2) Shrinkage Factor: v./v.^T, is'barrels of stock .tank oil @ 60° F. per barrel of saturated oil @ 10 2 0 PSI gauge and 10 9 o F. · 9 _ F. per (3) Fomation Volume Factor: v,^v./v, is barrels of saturated oil @ 102OPSI gauge and 1 0 o barrel of stock tank oil @ 60° F. tT'hhts~rr ana. l .y~es, ol~inio_.ns o.r.inter~..~, tions ar~..based on obse.rvattons and material supplied by tho client to whom.· and for who~e exclusive and confidential use. ~er~o[brot~_~? m. ~a~e%'rne ,n~te,,t~_rer~laOne or, opmx. on$ expressed represent t~,e .be~ st judgraent of Core Laboratories, Inc, (,11 errors .and omissions excepted): hut · : · ~oraro.r~,e~.., ~ne. ~na ~ts omcera an(~ empJoyeee, ass~lme no respons~Iht7 and make no warranty or representations as to the productivity, proper oper~- Component CORE i. ABORATORIES, I1.::. Pelrole#m I~.rervo~, Engine~ng DALLAS. TEXAS STATF. OF ALASKA COPY Page_ 13 ol 24 .' 1;~ile RFL 7158 Wen BP 27-1 1-14, - Rate 3 Hydrocar~n Analyses of Separator Products and Calculated Well Stream - Separator Liquid Separator Gas Mol Per Cent Mol Per Cent GPM Well Stream Mol Per Cent GPM Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane .n-Pentane 'Hexanes -Heptanes plus 6.01 11.08 O. 06 O. 66 2 I. 54 78.72 5.77 5.30 5.75 2.38 1.55 0.32 4. Z6 0.74 1.86 O, 18 3. 12 0.23 5.68 O. 17' 44.40 O. 22 '100.00 100.0'0 0.653 0.104 0.233 0.066 0.083 0.069 O. 100 1. 308 10.84 0.63 76.02 5.32 2.54 0.38 0.91 0.26 0.37 0.43 2.30 100.00 0. 697 0. 124 0.286 0. 095 0. 134 0. 175 1. 249 Z. 76'0 Properties of Heptanes plus API gravity @ 60° F. Specific gravity @ 60/60° F. Molecular weight 47.9 0. 7889 138 ~Calculated separator gas gravity (air: 1.000): Calculated gross heating value for separator gas: per cubic foot of dry gas @ 14.696 psia and 60° F. Primary separator gas collected @. 1020 Primary separator liquid collected @ 1020 Primary separator gas/separator liquid ratio Primary separator liquid/stock tank liquid ratio Primary separator gas/well stream ratio Stock tank "liquid/well stream ratio 103 0.746 1020 RTU psig and 109 'F. __psig and 109 'F. ~ , 22746 SCF/BbI@60°F. 1.2 50 Rbls @ 60° F./Bbl 95 Z. 81 MSCF/MMSCF 33.5 i Rbls/MMSCF 0. 786 135 l'h~se a~llmes, opinions er tnt~rvretatlons are ~ on ~atlons and ma~rlal supvlI~ br th~ e!i~t ~ whom, and for wh~ ~elustv, and ~nfl~t~l ~, ~is ~ is m~e. ~e interp~tations or opinions ~p~:~ ~p~nt the ~t judgmeat of ~ ~ra~ries, Inc. (all er~ and omt~io~ ~p~); b~ CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALI. AS. TEXAS Well 14 of RFL 7158 BP 27-11-14, 24 Rate 3 Pressure-Volume Relations of Reservoir Fluid at 19 7 o F. (Constant Composition Expansion) PSIG Volume Deviation Factor Z 6000 0.8079 5500 0.8440 5000 0.8894 4500 0.9474 4332 0.9714 4278 Reservoir Pressure 0.9797 4219 0.9884 4176 0.9951 4148 Dew Point Pressure 1.0000 __ 4118 1.0032 4083 1.0105 4047 1.0171 3938 1.0367 3731 1.0791 3371 1.1707 2986 1.3045 2601 1.4860 2297 1.6877 1940 2.0106 1667 2.3656 1468 2.7113 1316 3.0484 1189 3.3893 1042 3.9056 1. 073 1.028 0. 985 0. 944 0. 932 0. 928* 0. 924 0. 921 0. 919'* * .Gas formation volume factor = iv 397 MSCF/Bbl. ** Gas formation volume factor = 1. 369 MSCF/Bbl. ?hese analyses, opinions or interpretations are Based on observations and material supplied by the client to whom. and for whose exclusive and confidential use. 0 j.d )..d J..d 0 0 0 0 0 0¸ 0 0 ~ 0 0 ~ ~ 0 0 o o ADO]) V)I.SVI¥ :!0 0 ..~ ~.~ O~ 0 0 ~0 0 0', 0 0 ~0 · 0 0 0 0 0 N .L,T'I "~ 0 0 -,4 0 m -! × 0 M · 0 ,re 0',, m.~,. -,,1 rua Ua 0"', O O O O OO O O O N · · · · --,1 o ~,1N ',4D · o · · -...1o 00,4D o~ o Ol ~1~ N o · · · o o o o N O ~ o · .q .ffi · CL~$92 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS P~ge 17 of 24 Pile RFL 7158 Well BP 27-11-14, Rate 3 Retrograde Condensation During Gas Depletion at 197 o F. Pressure PSIG 4148 Dew Point Pressure 3500 2800 2'000 1200 700 0 Retrograde Liquid Volume Per Cent of Hydrocarbon Pore Space 0.0 0.5 1.3 2.1 2.5 2.5 2 CONF,.n' !r, STATE OF ALASKA COPY Properties of Zero PSIG Residual Liquid Gravity : 43° 9 °API@ 60° F. Density : 0.80 59 gms/cc @ 60° F. Mdlecular weight: 1 50 Core Laboratories; Inc. Reservoir Fluid Analysis P. L. Moses Manager These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is,made. The interpretations or opinions expressed represent the best judgment o[ Core Laboratories, Inc. (all errors and omissions excepted); but ~or~ l,aharntorion, lnc. and it~ officera an¢l ernnlov~es, assume no res~mnsibilitv and make no warranty or representations as to the Dro'ductivitv. Drover opera- 4.0 Company Well Field CORE LABORATORIES. INC. 'Pc~ge 18 of 24 Petroleum Rese~oi~ En~in~ring DALLAS. TEXAS File RFL ~ 158 Pressure-Volume Relations of Reservoir Fluid at 197e F. BP Alaska Inc. BP 27-11-14, Rate3 Prudhoe Bay Formation County State Sadlerochtt Sandstone Alaska 2.0 ,,4 1.0 0.0 0 100.0 ZOO0 3000 4000 5000 6000· Pressure- PSIG Page 19 of. 2,4,, Hydrocarbon Analyses of Produced Well Stream File RFL 7158 During Depletion at 197' 2'. ~ BI~ ZT-11- 1 Rate 4 0 1000 2000 3000 4000 Pressure - PSIG 1.15 CORE LABORATORIES. INC: Pe{Toleum Resert~i~ Engin¢~rin£ DALLAS. TEXAS Page 20 of_24 File RFL 7158 Deviation Factor'Z of Well Stream During.:Depletion at 197~ F. Company. BP Alaska Inc. Formation Sadlerochit Sandstone Well B lb 27 - 11 -. 14, R ate $ County Field Pru dhoe Bay State A la s ka 1. I0 1.05 1.00 O. 95 0.90 0.85 0.80 0.75 0 1000 2000 3000 4000 5000 6000 Pressure ~ PSIG 100 c~O 8O 7O 6O 5O 4O 3O 2O 10 CORE LABORATORIES. INC. Page~J~____ Petroleum Reservoir Engineering DALLAS. TEXAS File R~'Z, 7158 _ Volume of Well Stream Produced During Depletion Company BP Alaska J. nc,... Formation _$adlerochit Sandstone Well BP 27-11-1'4~_ Rate $ County__ Field Prudhoe Bay State Alaska '¥*" : ", 'I .............. ~ ..... ~ ..... :- ~ ~ .... -- ~ ..... 4 ................. ; ........ .;..~ _ -- i ' ; ' ' ' ' ' ~ ; ' : ' ' * ' : ' I.~?~ ~-.~-:--..~--~ ......... ~ .......... . ....... ~ ................... ~ ........ ~ ...... · ..... ~ .... ~ ..... J .... ,_: .... · .... 4 ........ :.~-'*'--,4-%-~ '*' ; ' , , : . . ' ' } , * , ' ..................... ~--. ..... I ..................................... .-*' ............ ~-( _. ...... + . .... ~ ~ ......... .~ : , . _(_. k _ , ~ . i . , , , , · .............. r ............ ~ * ~ . ;-: ; :.;. ~ .... { ....... , ,':',',."~ ................ :-~.]-:-~ ..... ........... .-:..~.-] .... .., .. ......... ~ ...... ~ .... ................ ~ .................... ~..; .......... ~..:~_ .......... '....l ...... ~ ...... ' ....... ~ .... ._. ~ :~ r . - ]-" ..... ] ~ ....... : 't ". "-i ~ '" : ~ .... t":'!' :": Y ....?" ,'d';-r"~ ...... _..<_:_.;.~ .~: ..... : ........ =,..;_=_~. .......... .--~.: L;_L _;_[ :.J ' ~ .' ~ : ~ ~X . . i";" ' L~, ' ~ II r7 .~"~'. ":-[:t ...... (l': ......... I ....:"~'~ .......... 7~'I'-~''-! ........... :''-r ......: ..... ~'~!;"'~ ......... ~'-+-'I-: ..... ~ .... ;-~-'P! .....~-*.4- r. T . t t · ~ ;. ;~;¥_; ~ ;'~.];t'~ .=';~ L L~ ;: .Tf':~.Y '~' ;'T~"]= ~;' - ~ ..... :' ~ ...... ' ....... ...... ~ = .... : ':1 -'; .... ~ ."~ ....... : .... ;"* -~'~ ..... ~ +~ ......... ~'-~-'*~+~-~-- -'-~: .... F *~ ....... ~ ........ ~ ~-! ~ ...... ~ ~-~' ' .....~ ....... ;'-~ '"t + ..................... : .... i :4..~ ~ ;4: ~4-.~--~-.~ --~4~...;-.~4-~.-~ .-. . , -~, ' ' ~ ,, -';-i ....:"i 'r?'t-, ......... ;'.. !i '+'fi': ;"~ .... :~ - =~ :A.-t-;.~ -: ..... : '- ~ t-~ '~' :.4-?-+-i ...... . . ....... :'~' ~ . : . t~ . . . ~ .......... . ............... r ........... ~ ..... ~ ...... ~ ........ ~-~,'-~- ~-i ....... !-i--;-- .... , ;.. i-..;: .... : :.-:--..4 :.;-' .......... ~-~'~ ~: ..... , .... t-," ~-: ....... =-~T~ ....... :,i_~_'~ ~.''-4 t'~-~'' --" ;:' . -~-+---. ..... t-~-.-~*-~--~,-.-~.-; ............. ~--=.+:-~-~ ........... ; ........ , ; , ., , . . , ~ . . ~ ~ . . ~ ' , , . ; . . . ~ _ , ~ , , . : 0 I000 2000 3000 4000 5000 6000 7000 8000 -' : Pressure-- PSIG 8OO Company Well Field CORE LABORATORIES. INC. Petroleum Reservoir Engince~'ing DALLAS. TEXAS Cumulative :Recovery :During Depletion BP Alaska Inc. Formation~ Sadlerochit sandstone BP 27-11-14, Rate 3' County Prudhoe Bay State Alaska Page ZZ of~ File RFL ? 158 16' 700 600 500 400 300 ZOO 100 0 0 1000 2000 .3000 4000 5000 6000 14 12 10 8 Pressure .. PSIG 8OO CORE LABORATORIES. INC. Page 23 of 24 Petroleum ~e~ervoir ~.gmeeriflg DALLAS. TEXAS File RFL 7158 C~ulative Recovery - "Plant Products" tn Primary Separator Gas Company Well Field BP Alaska Xnc. BP 27-11-14, Rate Prudhoe Bay · Formation County State Sadlerochit Sandstone A taska 700 0 · 600 500 400 300 200 100 0 0 1000 ZOO0 3000 4000 5000 6000 Pressure - PSIG 8.0 7.0 6.0 5.0 4.0 3, ¸0 2.0 1.0 0.0 Company Well Field CORE LABORATO.RiE$, iNC. '( Pg~ro/eum I~eservoir Engineering ., DALLAS. TEXAS Retrograde Condensation During Depletion Page File RFL 7158 BP Alaska In'c. BP 27-11-14, Rate3 Prudhoe Bay Formation~ County State Sadlerochit Sandstone Alaska 0 1000 - 2000 3000 4000 5000 6000 Pressure - PSIG CORE LABORATORIES, INC. Petrolet. tm Reservoir Engineering DALLAS. TEXAS 75Z07 August 20, 1969 AU6 ~1 1959 -RESERVOIR FLUID ANALYSIS BP Oil Corporation P. O. Box4-1395 Anchorage, Alaska 99503 Attention: Mr. H. J. Clarke CONFIDENTIAL. $ rE OF ALAS COPy Subject: Compositional Dele rminations Separator Gas and Liquid Samples BP Put River No. 1 Well Alaska Our File Number: RFL 5875 Gentlemen: .. Presented in this report are the results of compositional determinations performed in our laboratory in Dallas. The fluids analyzed were sePa- rator gas and liquid samples collected from the BP Put River No. 1 well on June 27 and 29, 1969. As a check of the validity of the samples, the opening pressures of the gas samples and the saturation pressures of the liquid samples were determined at room temperature. These data are shown on page one. The gas samples opened reasonably near the reported separator condi- tions with the exception of Sample AFS 22B. The li ui~ sa~[~les how- ever, ~to b_9_.~_y.e~j/.:~q~es_tiona~_l.e, The AFS 23 samples were collected at 10 psig, rather than at the separator pressure of 50 psig, and are therefore somewhat deficient in the lighter hydrocarbons, principally methane. The AFS 24 samples were reportedly collected at 165 psig and 70° F.; however, the saturation pressures of the sam- ples were found to be from 33 psig to 59 psig at 75° F. These samples also appear to be deficient in methane'. The composition of one sample from each group was measured. These analyses were mailed to you in preliminary form on August 1t, 1969, and on August 18, 1969 you instructed us to issue the final report. Well stream calculations would surely be erroneous, and were not made. BP Oil Corporation BP Put River No. 1 Well '! CONFIDENTIAL. STATE OF/',~!ASKA COPY -. Page Two It has been a pleasure to cooperate with BP Oil Corporation by perform- ing these analyses, l~!ease let us know if we may be of any further -service or if you have any questions. Very truly yours, -I~LM:JB:dr 7 cc. - Addressee .. Core Laboratories, Inc. Reservoir Flu. id Analysis 'P. L. Moses Manager CORE LABORATORIES, INC. Petrole#m Re. rervoir Eng~neering DAli. AS. TEXAS CONFID NT!AL STATE OF , ALASKA COPY Page 1 of 5 ,, File RFL 587.5 ' Well BP ]:h~t River 'N'c~_ 1 Separator Gas and Liquid Sample Data Gas Sample Data Zone Sample Sampling Conditions Upper AFS ZlA 50 PSIG @ 34° F. Upper AFS ZlB 50 PSIG @ 34° F. Upper AFS 21C 50 PSIG @ 34° F. Whole AFS 22A 165 PSIG @ 70° F. Whole AFS 2ZB 165 PSIG @ 70° F. Whole AFS 22C 165 PSIG @ 70° F. Liquid Sample Data Z one Sampl e_ .Sampling Conditions Upper AFS 23A 10 PSIG @ 34° F. Upper AFS 23B 10 PSIG @ 34° F. Whole AFS 24A 165 PSIG @ 70° F. · Whole AFS 24B 16'5 PSIG @ 70° F. Whole AFS 24C 165 PSIG @ 70° F. Whole AFS 24D 165 PSIG @ 70° F. Openi.ng C onditions 60 PSIG @ 75° F. 63 PSIG @ 75 ° F. 60 PSIG @ 75 ° F. 150 PSIG @ 75° F. 198 PSIG @ 75 ° F. 150 PSIG @ 75 ° F. Saturation Conditions 10 PSIG @ 75° F. 15 PSIG @ 75° F. 59 PSIG @ 75© F. 59 PSIG @ 75 © F. 55 PSIG @ 75° F. 33 PSIG @ 75 © F. These anal~rses, opinions or interpret~%tiorm are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opiaions expressed represent the best judl~ment of Gore Laboratories, Inc. (all errors and omissions excepted); but Gore Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion, or profitahlene~ of any oil. gas or other mineral well or sand in connection with which such repor~ is used or relied upon. Well · Field CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS CONFID TIAL STATE OF A[^SK COPY BP Oil 'C, nrnnrntinn Formation, · BP Put River No. ] County State Ala$ ka Page 2 of File T~WT, 5875 5 HYDROCARBON ANALYSIS OF Separator GAS SAMPLE COMPONENT I MOL PER CENT I G P M Hydrogen Sulfide Carbon Dioxide 14.37 Nitrogen 0.35 Methane 72.05 Ethane 7.78 1. 960 Propane 3.64 0.9 99 i~o-Butane 0.41 0.1 34 n-Butane 0.86 0. 270 iso-Pentane 0.15 0.055 n-Pentane 0.16 0.058 Hexanes 0.08 0.033 He~tanes plus 0.1 5 ,0. ,0,6 8, 100.00 3. 577 Calculated gas gravity (air ~ 1.000) ~ 0.7.98 Calculated gross heating value -- 1 023 BTU per cubic foot of dry gas at 14.696 psia at 60° F. Collected at 50 psig and 34 o F. Sample AFS 2lA These analyse~, opinions or interpretations are based on observations and material supplied by the client to whom. and for who~e exclusive and confidential uae, this report is made. The interpretations or opinions expresse4 represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted): but Core Laboratories. Inc. and its oflicer~ and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion. or profitablenems of an}' oil. gas or other mineral well or ~and in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum ~e~ervoir Engineering K~A L.I_A$. T£XA$ Company CONFIDENTIAL STATE OF ALASKA COPy Oil Corporation FormatiOn Well B P P-t R ire r No_ 1 County Field State A1 a ska Page 3 of 5 File RFL 5875 HYDROCARBON ANALYSIS OF Separator GAS SAMPLE Hydrogen Sulfide Carbon Dibxide Nitrogen Methane Ethane Propane i~o-Butane n-Butane iso-Pentane n-Pentane Hexanes He~tanes plus 14.19 0.30 74.40 7.09 1. 786 2.74 O. 752 O. 28 O. 091 0.55 0.173 0.10 0. O36 0.11 0.040 0.05 0. 020 0.19 0. 086 100.00 2. 984 Calculated gas gravity (air ~ 1.000) -- O. 776 Calculated gross heating value -- 994 - BTU per cubic foot of dry gas at 14.696 psia at 60° F. Collected at 165 psigand 70 OF. Sample AFS 22A The~e analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for. whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); but Core Laboratories. Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper o~erao $io~, er profit~blenees of ~ny oil. gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLA$.. TEXAS Page 4 of 5 File RFL 5875 Company Well Field BP Oil Corporation . BP Put River No. 1 Formation County State · Alaska HYDROCARBON ANALYSIS OF MOL WEIGHT COMPONENT PER CENT PER CENT Senarat. or Liou~d SAMPLE D~NSITY (~ 60e F. e' APl MOLECULAR GRAMS PER CUBIC ~ 60° F. WEIGHT CENTI M ET ER Hydrogen Sulfide Carbon Dioxide 0.24 0.05 Nitrogen T fac e T rac e Methane 0.48 0.03 Ethane 1.23 0 16 Propane 2.97 0 55 isooButane 0.8 6 0.21 n-Butane 2.98 0.73 iso-Pentane 1.34 0.41 'n-Pentane 2.08 0.64 Hexanes 3.35 1.22 Heptanes plus 84.4 7 96.00 100.00 100.00 CO ID . r COp'}, 0.8962 26.2 268 Collected at 10 psig and 34° F. Sample AFS 23A These. analy~, opinions or interpretations are based on observations and material gui)plied by the client to whom. and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgmeng of Core Laboratories. lne. (ali errom and omissions excepted): but Core Laboratories. Inc. and its officers and employees, assume no responsibility and make no warrant}' or representations as to the productivity, proper opora- tion, or profitableness of an}' oil. gas or other mineral well or sand in connection with which such report is used or relied upon. CORE .LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Company Well · Field BP Oil Corporation BP Put River No, 1 Formation County State Ala aka Page 5 of 5 File_ RVL 5R75 HYDROCARBON ANALYSIS OF MOl. WEIGHT COMPONENT PER CENT PER CENT Separator Liquid SAMPLE I:YENSITY ~ 60° F. GRAMS PER CUBIC CENTI METER APl 60e F. MOLECULAR WEIGHT Hydrogen Sulfide Carbon Dioxide 0.69 0.13 Nitrogen T rac e T rac e .. Methane 1.53 0.11 Ethane 1.27 0.16 Propane 2.46 0.47 lap-Butane 0.73 0.18 n-Butane 2.56 0.65 iso-Pentane 1.22 0.38 n-Pentane 1.90 0.59 Hexanes 4.00 1 .-4 9 Heptanes plus 8 3.64 95.84 1 00. O0 100. O0 CONFtDrNTIAL STATE OF ALASKA COPY O. 8920 27.0 264 .Collected at 165 psig and 70° F. Sample AFS 24C Core Laborato'ries, Inc. Reservoir Fluid Analysis P. L. Moses Maria ge r These analyses, opinions or interp,~tations are based on observations anti material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted): but Core Laboratories. Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TIE. XAS 7.5207 August 15, 1969 99503 BP Oil' Corporation P. O. Box 4-1395 Anchorage, Alaska RESERVOIR FLUID ANALYSIS CONFIDENTIAL' STATE OF ALASKA COPY Attention: Mr. H. J. Clarke Subject: Reservoir Fluid Study BP Put River No. 1 Well ~ AFS 26 Alaska Our File Number: RFL 58?7 Gentlemen: Surf u. xd __ s~a~rn~_=_ ~l_es from the subject well were delivered to our labo- ratory in Dallas to be used in a reservoir fluid study. The results of this study are presented on the following pages. The bubble-point'pressures of Samples AFS Z6A, B and C were measured at room temperature, and were determined to be 3792 psig, 3784psig and 3786 psig, which is considered to be excellent agreement. Fluid from Sample A was used in the entire reservoir fluid study. The fluid was charged to a visual cell and the bubble-point pressure was determined to be 3905 psig at 100° F., 4143 psig at 150° F. and 43Z1 psig at ZOO° F. This latter value is in very close agreement with the reported sampling conditions of 4300 psig at 198° F., which is an indication that the fluid was saturated in the tubing at the time of sampling, l~ressure-volume relations were measured at each of these temperatures, and the specific Volume was calculated at each pressure. This information was mailed to you in preliminary form on August 1, 1969. As you requested, the expansion was continued to below 100 psig at 150° F. and 100° F. The fluid was subjeCted to differential pressure depletion at g00* F. and evolved 837 standard-cubic feet of gas per barrel of residual oil at 60* F. The associated BP Oil Corporation ' BP Put River' No. 1 Well AFS Z6 Page Two formation volume factor was found to be 1.419 barrels of saturated fluid per barrel of residual oil. The viscosity of the l~.quid phase was measured during a similar liberation and varied from 0. 810 centipoise at the bubble- point pressure to 3. 286 centipoises at atmospheric pressure. A multi-stage separator test was performed at 120° F. with stage pressures of 600 psig, 100 psig and 0 psig. The reservoir fluid composition was mea- sured by low temperature, fractional distillation. Thank you for allowing us to be of service by performing this reservoir fluid study for you. Please do not hesitate to call on us if you wish to discuss the results or if we may be of any further assistance. Very truly yours, I~LM:JB:dl 7 c'c. - Addressee Core Laboratories, Inc. Reservoir Fluid Analysis P..L. Moses Manager COIVFID ':, ITiAL ZTA TE OF ALASKA COPy COmpany Well Field Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas-Oil Ratio Production Rate Separator Pressure and Temperature Oil Gravity at 60° F. Datum Original Gas Cap CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page 1 of 17 File RFL 5877 BP Oil.Corporation Date Sampled June 30, 1969 BP .Put River No. t AFS 26 COunty State Alaska FORMATIO~I CHARACTERISTICS "Whole Zone" WELL CHARACTERISTICS PSIG @. PSIG. ,19 Ft. SCF/Bbl Bbl/Day °F. .. ?.AP1 Ft. Subsea Elevation Total Depth · Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge Normal Production Rate Gas-Oil Ratio Separator Pressure and Temperature B,ase Pressure Well Making Water % Ft. .Ft. 4300* In. to Ft. Bbl/D/PSI @ Bbl/Day PSIG @ Ft. , .19 198' °F.@ ~Ft. PSIG, Bbl/Day SCF/Bbl °F. .PSIA Cut' SAMPLING CONDITIONS Sampled at Status of Well Gas-Oil Ratio Separator Pressure and Temperature Tubing Pressure Casing Pressure Core Laboratories Engineer Type Sampler 'Ft. , PSIG, , .SCF/Bbl °F. PSIG PSIG REMARKS: * 'Sampling conditions.' . CORE LABORATORIES, INC. Petraleum Re~ert,o~r Engineering DALLAS. TEXAS Page File Well 2 of 17 RFL 5877 BP Put River No. AFS 26 VOLUMETRIC DATA OF Reservoir Fluid SAMPLE 1. Saturation pressure (bubble-point pressure) 39105 . PSIG @ V@ 100°F 2.' Thermal expansion of saturated oil @ 6000 PSI --V @ 74 °F -- 1. 01363 8. Compressibility of saturated oil @. reservoir temperature: Vol/Vol/PSI: l~'om 6000 PSI to 5500 PSI-- From 550'0 PSI to 5 O00 PSI -- From 5000 PSI to 3905,PSi-- 100 OF. 7.10 x 10-6 7, 38 x 10-6 8. 08 x 10-6 4. Specific volume at saturation pressure: ft S/lb 0.02041 @, 100 oF.. CONFIDENTIAL STAT , OF/,LASKA COPY .. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for whose exclusive and confidential use, this report is made. 'l~he interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (ail errors and omissions excepted): but CORE I..AIBORATORIES, INC. Petroleum Reservoir Engineering DAI..L..AS. TEXAS Page Well 3 of 17 · RFL 5877 BP Put River No. 1 AFS 26 Pressure-Volume Relation of Reservoir Fluid Sample at 100° F. Pre s sure, Relative Specific Volume, PSIG Volume Ft3 / Lb 6000 0.9840 0.02008 5500 0.9875 0.02015 5000 0.9911 0.02023 4700 '0.9934 0.02028 4400 0.9959 0.02033 4300 0..9967 0.02034 4200 0.9974 0.02036 4100 0.9983 0.02038 4000 0.9992 0.02039 3905 1.0000 0.02041 3835 1..0023 0.02046 3775 1.0043 0.02050 3548 1.0129 0.02,067 3144 1.0331 0.02109 2735 1.0655 0.02175 2384 1.1093 0.02264 2058 1.1696 0.02387 1768 1.2550 0.02561 1502 1.3727 0.02802 1276 1.5230 0.03108 1088 1.7059 0.03482 932 1.9224 0.03924 735 2.3355 0.04767 558 2.9834 0.06089 402 4.0483 0.08263- 382* 4.3027 0.08782 295* 5.5176 0.11261 -215. 7.3839 0.1'5071 153. 10.3023 0,21027 98'.' -15.0714 0.30761 Measured separately. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential us~, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); but Core Laboratoriez..Inc. and its officers and employee~; assume no respomsibility .and make no warranty or representations as .to the productivity, proper opera- tion,' or profitableness of any oil. gas or other mineral well or sand in connection with which such r~port is ua~l or relied-upon. CORE LABORATORIES· INC. . Petroleum ReservoiT F-ngineering DALLAS, TEXAS Page 4 al. 17 File R~"L 5877 PRESSURE-VOLUME RELATIONS OF RESERVOIR FLUID a~; !00e Fo . i 4.0 3.0 2,0 1.0 0.0 Company BP Oil Corporation Formabcn "Whole Zon~" I Well BP Put River No. 1 AFS 26 County Field State Alaska 0 1000 2000 3000 4000 5000 6000 PRESSURE: POUNDS PER SQUARE INCH GAUGE CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TE. XAS Page 5 of File RFL 5877 Well AFS Z6 17 BP Put River No. 1 VOLUMETRIC DATA OF Reservoir Fluid SAMPLE CONFIDENTIAL OF ALASKA COPY 1. Saturation pressure (bubble-point p~ssure) 4.143 PSIG @ 150 oF. 2. Thermal expansion of saturated oil @ 6000 PSI V @ 150 °F =V@ 74 °F -- 1.04201 3. Compressibility of saturated oil @ reservoir temperature: Vol/Vol/PSI: F~'om 6000 PSI 'to 5500 PSI-- 8.51 x 10~6 From 5500 PSI to 5000 PSI-- 8.86 x 10.6 From 5000 PSIto 4143 PSI "9.58,x 10-6 4. Specific volume at saturation pressure- ft :/lb 0. 02100 @ 150 oF. · v~,,~,~ =,~Qlv~,~. c, nlnions or internretations are based on observations and .ma. ter!al, s?pplled blt the client to whom, and for whose exclusive and confidential use, Pressure, PSIG CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALI. Ab. TEXAS Page .6 of 17 File RFL 5877 Well BP Put River No. 1 . AFS 26 Press,re- Volume Re la ti onof r~ ~ CONF/0~ Reservoir Fluid Sample at 150" ~F~'/LI;~ /l Relative Specific Volume, Volume Ft3 / Lb 6000 0.98 z o. ozo6s 5500 0.9874 0.02074 5000 0.9918 0.02083 4500 0. 9964 0..02092 4400 0.9974 0.02094 4300 0.9983 0.02096 4200 0.9994 0.02099 4143 1.0000 0.02100 ~077' 1. 0023 O. 02105 4010 1.0050 0.02111 3812 1.0137 0.02129 3374 1.0398 0.02184 3012 1.0702 0.02247 Z670 1.111Z 0.02334 2318 1.1733 0.02464 Z008 1,2565 0.02639 1710 1.3714 0.02880 1454 1.5181 0.03188 1252 1.6860 0.03540 1068 1.'8963 0.03982 834 Z. 3039 0.04838 632 2.9366 0.06167 452 3.9749 0.08347 443* 4.0796 0.08567 352* 5.0797 0.10667 257* 6.8949 0.14479 182' 9.7310 0. Z0435 , 118. 14.3897 0.30218 84* 19.0477 0.40000 *Measured separately. ' 'I'hese analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted): but Core Laboratories, Inc. and its oliicers and emp!oyee.s, as.s. ume no.r.~ponslbilit, y and..?mk.e. 90 wa. rranty .or. repre, sentati.o.n,s as to the productivity, proper opera- 4.0 Company Well Field CORE LABORATORIES, INC. Petroleum Rese.~oir Engiaeering DALLAS, TEXAS Page 7 6f 17 Die RFL 5877 PRESSURE-VOLUME RELATIONS OF RESERVOIR FLUID BP Oil Corporation BP Put River No. 1 AFS 26 Formation County State "Whole Zone" Alaska z.o 1.0 0.0 1000 2000 3000 4000 ~PRESSURE: POUNDS PER SQUARE INCH GAUGE 5000 6000 CORE LABORATORIES, INC. Petroleum Reserz,oir Engineering DAI. L.A$. TF. XAS Page 8 ,,, of 17. File RFL 5877 Well BP l~ut River AFS Z6 VOLUMETRIC DATA OF fOIVFIDF_IVTIAL :: O? ? !ASKA COPy Reservoir Fluid SAMPLE 1. Saturation pressure (bubble-point pressure) 4321 PSIG @ 200 °F. 2. Thermal expansion of saturated oil @ 6000 PSI -~- V @ 200 oF V @ 74 OF 1.o7z55 3. Compressibility of saturated oil @ reservoir temperature: Vol/Vol/PSI: Ih-om 6000 PSI to 5500 PSI -- From 5500 PSI to 5000psi-- From 5000 PSI to~ PSI -- 9.85 x 10-6 10.38 x 10-6 11.58 × 10-6 4. Specific volume at saturation pressure: ft :/lb 0.02164 @ Z0.0..o.F. CORE LABORATORIES, lNG. Petroleum Reservoir Engineering DALLAS. TEXAS 75207 Page File Well Reservoir Fluid. SAMPLE TABULAR DATA 9 .,,of 17 RFL 5877 BP Put River No. 1 A FS 26 Pi~'ESSURE PBI GAUGE 6000 5500 .5200 5000 4900 4800 4700 4600 4500 4400 4321 4272 4229 4138 4000 3893 3604 3600 3267 3200 2928 2-794 2558 2395 2222 2000 1901 1620 1600 1404 IZ00 I Pressure- Volume Relation [ @ Z00* F. Relative Volume of [Sp. Vol., Oil and Gas, V/Vsat [Ft3/Lb 0.9821 0.02125 0.9870 0.02136 0.9901 0.02143 0.9921 0 02147 0.9932 0102150 0'9943 0.02152 0.9954 0.02154 0.9966 0.02157 0.9978 0.02159 0.9991 - 0.02162 1.0000 0.02164 1.0023 0.02169 1.0042 0.02173 1.0091 0.02184 1. 0224 0.0ZZlZ 1.0420 0.02255 1.0717 0.02319 1.1117 0.02406 1.1721 0.02536 1.2532 0.02712 1.3652 0.02954 1.5082 0.03264 1.6617 0.03596 1. 8667 0. 04040 DIFFERENTIAL LIBERATION @ 200 °F. GAS/OIL RATIO LIBERATED PER BARREL OF RESIDUAL OIL GAS/OIL RATIO IN SOLUTION PER BARREL OF RESIDUAL OIL RELATIVE OIL VOLUME, V/Va COIVFfD.etWIAL STATE OF ALASKA COPy 0 837 1.393 1.400 1. 404 1. 408 1.410 1.411 1.412 1.414 1.416 1.417 1.419 70 767 1. 389 148 689 226 611 1.356 1. 325 303 534 373 464 1. 293 1.266 445 392 1.237 514 323 1.211 582 255 1. 184 v = Volume at given pressure v,^-,.: Volume at saturation pressure and the specified temperature. -v. -- ResidUal oil volume at 14.7 PSI absolute and 60° F. ,. 'l'heze analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whoz~ exclUSive end confidential u~e, this rep'ort is made. The interpretations or opinions expressed rep,'esent the best judgment of Core Laboratories, Inc. (all errora and omissions excepted); but PRESSURE F'~I GAUGE CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS 75207 Page File Well Reservoir Fluid' SAMPLE TABULAR DATA 10 ,of 17 RFL 5877 BP Put River No. 1 AFS 26 Pressure-Volume Relation @ Z00° F. Relative Volume of } Sp. Vol., Oil and Gas, V/Vsat[ Ft3/Lb DIFFERENTIAL LIBERATION @ ~-0'0 "F. GAS/OIL RATIO LIBERATED PER BARREL OF RESIDUAL OIL GAS/OIL RATIO IN SOLUTION PER BARREL OF RESIDUAL OIL RELATIVE OIL VOLUME, V/V. 936 798 704 50Z 400 140 0 2. 2639 O. 04899 2.8834 0.06240 3.9011 0.08442 654 183 1.154 . . 724 113 1. 125 780 57 1. 101 837 0 1.061 @ 60 ° F. : 1.000 Gravity of residual oil: 27. go AP1 @ 60° F. CONFIDENTIAL STATE OF A,LASK COPY v -- Volume at given pressure v,^,. -- Volume at saturation pressure and the specified temperature. v, -- Residual oil volume at 14.7 PSI absolute and 60© F. Th~.~e analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and con/hlential use, · ' -, ......... .~- ~.-..+ ;,,.~ .... , nF C.~,.. Laboratories. Inc. (ali errors and omissions excepted); but CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page 11 of File RFL 5877 17 Well BP Put River No. 1_ AFS 26 Differential Pressure Depletion at 200 o F. Pressure Oil Density Gas Deviation Factor PSIO . ,Gms/Cc .Gravity Z 4321 0.7403 4000 0.7475 0.801 0.917 3600 0.7554 0.797 0.891 3200 0.7634 0.792 0.878 2794 0.7716 0.789 0.867 2395 0.7789 0.788 0.868 ZOO0 0.7869 0.788 0.882 1600 0.7942 0.793 0.891 1200 0.8024 0'.805 0.910 798 0.8116 0.839 0,'941 400 0.8202 0.912 0.966 140 0.8260 1.069 0 0.8390 1.531 STi : TE OF A..ASLt , ! COPY These analyses; opinions or interpretations are based on observations and material supplied b~r the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted): but Core Laboratories. Inc. anti its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, prol~r opera- .......... , ,. ~ ..... L ........ ~. -. ...... ~ .- L_~:_.i ..... CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page File Well 1Z . of . 17, RFL 5877 BP Put River No. 1 AFS 26 Oil Viscosity at Z00° F. Pressure, Viscosity, PSIG Centipois e s 6000 O. 9O9 5500 0. 877 5200 0o861 4900 0.848 4500 0. 821 4321 0.810 4000 0.838 3600 0. 881 3200 00 945 2794 I. 007 2395 1o 085 2000 1.206 1600 1. 352 1ZOO 1. 537 798 1. 736 400 2.095 0 30286 CONF!D,NTIAL OF ALASKA COPY Theae analyses, opinions or interpretat|ons are based on observations and material supplied b_y the client to whom, 'and for who~e exclusive and confi~lential uae, this repot~ is made. The interpretations or opi.lons expressed represent the best judgment of Gore Laboratories, Inc. '(all errors and omissions excepted); but Core Laboratories. Inc. and its olticers and employees, a:;sume no rest~ansibility and make no warranty or representati.on_a as to the productivity, proper opera- SEPARATOR PRESSURE, i:~1 GAUGE CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS Page 13 of. File RFL 5877 17 SEPARATOR TESTS OF Well Reservoir Fluid BP Put River No., 1 AFS 26' SAMPLE SEPARATOR TEMPERATURE, e F'. i I Oil GAS/OIL RATIO Density STOCK TANK GRAVITY. APl (~ 60e F. Formation Volume Factor (3) .Separator Volume Factor (4) SPECIFIC GRAVI'TY OF FLASHED GAS 600 120 to 100 120 to 0 120 650 0.8396 114 0.8551 46 1. 099 0. 763 1.053 0.911 0. 8665 Z7.7 1. 390 1. 026 1. 162 CONFLOqNTIAL STATE OF ALASKA COP.y (1) Gas/Oil Ratio in cubic feet of gas @ 60° F. and 14.7 PSI abs'olute per barrel of stock tank oil @ 60 ° F. (2) Oil Density in grams per cubic centimeter of oil @ indicated pressure and temper- ature. (3) Formation Volume Factor is barrels of saturated oil @ 4321 PSI gauge and Z00° F. per barrel of stock tank oil @ 60 ° F. (4) Separator Volume Factor is barrels of oil @ indicated pressure and temperature per barrel of stock tank oil @ 60° F.' These analyses, opinions or interpretations are barred on observations and material supplied by the client to whom, and for whose exclusive and confidential use. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); but ~,~r~ l,n~,t'*..~fn~;~ ln~ ~.~1 ;,a ~fl;~.o ~1 ~.~l.~,~a ~.,o,..~ ~.~ ~.~t,~..o;¥,;i;~.. ,,~A ~.1.~ ~ ,..o~,.. ~..,. ~oe~.~+~flc~.~ ~ t~ +ho .~c~l,,o~;~;fxr t~rn~ Company Well Field CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS BP Oil Corporation Formation BP Put River No. 1 AFS 26 County. Page 14 of File RFL 5877 "Whole Zone" 17_ State Alaska HYDROCARBON ANALYSIS OF COMPONENT MOL PER CENT WEIGHT PER CENT Reservoir Fluid .SAMPLE DENSITY (~ 60e F. · APl MOLECULAR GRAMS PER CUBIC ~ 60e F. WEIGHT CENTIMETER .Hydr.ogen Helium Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus Trace 0.01 Nil 9.11 0.45 44.13 5.11 3.03 O.83 1.35 0.76 1.16 1.54 32.52 100.00 Trace 0.01 Nil 3.?9 0.1Z 6.69 1.45 1.27 0.45 0.74 0.52 0.79 1.25 82.92 100.00 0.8935 26.7 270 Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manager These analyses, opinions or interpretations ar~. based on observations and maferia! supplied by the client to whom, and ;,o~ whose exclusive and confidential u~.~., 4.0 3.0 Z.0 1.0 0.0 CORE LABORATORIES, INC Page 15 o! 17;' Petroleum Reser~oi~ Engineering File RFL 5877 DALLAS. TEXAS PRESSURE-VOLUME RELATIONS OF RESERVOIR FLUID at 200' F. Coml:x:ny , ]31' Oil Corporation .... Formatmn __:'Whole Zone" . Well BP Put River No. I AFS 26 County Field State Alaska 0 * 1000 Z000 3000 4000 5000 6000 PRESSURE: POUNDS PER SQUARE INCH GAUGE 1600 1400 lO00 800 60O 400 2OO CORE LABORATORIES. INC. Page Petroleum Resen, oir Enginte~i.g DALLAS. TEXAS File RFL 5877_ DIFFERENTIAL VA~RIZATION OF RESERVOIR ~UID at ZOO" F~ Company BP Oil Corporation Formotion "Whole Zone" Well BP Put River No. 1 AFS 26 .... County Field State A la s ka I I , , .- ,,' ,qr . . ...... ~ . ~ . . ' /~~ r r r ,. . , ~ .... . ~ .. , , . .. ~/ , .. ,, , , 0 1000 2000 3000 4000 5000 6000 1.80 1.70 1.60 1.50 1.40 1.30 1.20 1.10 1,00 PRESSURE: POUNDS PER SQUARE INCH GAUGE · 4.0 Coml:x~ny Well ,, Field CORE LABORATORIES. INC. DALLAS. TEXAS Page ........ 17 of -3_2L File RFL 5877__ VISCOSITY OF RESERVOIR FLUID BP Oil Corporation BP Put River No. 1 AFS 26 Formation County State Alaska 3,5 3.0 Z.5 2.0 1.5 1.0 0,5¸ 0.0 1000 Z000 3000 4000 PR£$SURIq: POUNDS PI::R SQUARE INCH GAUGE 5000 6.000 CORE LABORATORIES, INC. .Pelroleum Reservoir Engirm~ring DALLAS, TEXAS 75207 'August 13, 1969 RESERVOIR FLUID ANAI. YSIS BP Oil Corporation P. O, Box 4-1395 Anchorage, Alaska 99503 COIVFID VTIA STATE OF ALASKA LCOPy Attention: Mr. H. J. Clarke Subject: Reservoir Fluid Study BP Put River No. 1 Well Upper Zone Alaska Our File Number: RFL 5876 Gentlemen: Two ,s...,ubsu~£ace~s identified as AFS 25A and AFS 25B were delivered to our laboratory in .Dallas. Specified tests were performed with these samples, and the results are presented in this report. Both samples were found to have bubble-point pressures of 3720 psig at 74° F. Fluid from Sample AFS ZSB was charged to a visual cell and heated to 200° F. The fluid was found to have a bubble-point pressure of 4294 psig at this temperature, No further testing was requested. We are now holding the samples pending further instructions, If you desire any. other testing or if we may be of further service, please do not hesitate to contact us. Very truly yours, Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manager PLM:JB:dr 7. cc. - Addressee CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page 1 of, 3 File RFL 5876 Well BP Put River NO. 1 AFS Z5 VOLUMETRIC DATA OF CONFID NTIA STATE OF ALASKA L' ' COpy Reservoir Fluid :SAMPLE I. Saturation pressure (bubble-point pressure) 4294 V @ 200 OF 2. Thermal expansion of saturated 'oil @ 6000 PSI -- V@ 73 OF ' 3. Compressibility of saturated oil @ reservoir temperature: Vol/Vol/PSI: From 6000 PSI to 5600 PSI -- From 5600 PSI to. 4900 PSI-- From 4900 PSI to_42_gA_ PSI -- PSIG @ 200 OF. 1. 07310. 9.43 x 10-6 10.7Z x 10-6 11.32x 10-6 These analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for whose exclusive and confidential use, this repo,~ is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted): but Core Laboratories. Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, prol~er opera; tion. or nrofitableness of a.mr oil, ~as or other mineral well or sand in connection with which such reoort is used or relied uoon. CORE LABORATORIES, I NC. Petroleum Reservoir Engineering DALLAS, TEXAS Pressure-Volume Relations of Reservoir Fluid at (Constant Composition Expansion) Pressure PSIG Bubble Point Pressure 6OOO 5600 5200 4900 4600 4500 4400 4294 4243 4198 4176 4060 3801 3487 3120 2768 Z398 2062 1742 1288 948 681 470 'Page 2 of. File RFL 5876 Well BP Put River No. 1 AFS 25 200°F. R'elative .Volume 0. 9820 0. 9857 0. 9899 0.9931 0.9964 0.9977 0. 9987 1. 0000 1. 0027 1.0050 I. 0062 1.0118 1. 0249 1.. 0494 1.0860 1.1339 1.2065 1.3039 1.4384 1.7702 2.2388 2. 9775 4.1918 Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manager These analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Gore Laboratories, Inc. (all errors and omissions excepted); but Gore Laboratories, Inc. anti its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. 5.0 4.0 3.0 Z.O 1.0 0.0 .. CORE LABORATORIES. I PmoZ~m l~.~.,oi~. E,&,i,~ri,g Poge 3 o! 3 DALLAS, TEXAS File RtL, 5876 Pressure-Volume Relations of Reservoir Fluid at 200' F. Company BP Oil Corporation Formation Upper Zone Well BP Put River No. 1 AFS 25 County Field State· Alaska --~'*' .' r-t-*. .... ~' ~ t ' · , ' , , -t ,-- - i --;-~-~- - ' | ---4M--I------J-' 4-J- ,_~-__,2 ~ ~4-J-- ---k.J~-t--~t-~--i--:4- i i I I : i i i i ; I ! I · I ~ ' ! ! : i i j J ! , : ~, !- ~',--?~--Y-'I'''-m-~-: -ff-4-'~h~--' ' ' ' 'Jr-~-3--t--'-I'-~, I ;~-.' ,' .'--4--~' ' -~4-.---~-~.' '-----4-~-4---~-: · ~-F~-~L'-~ ,--~-~-,-FF~-~-.,-~-~-I- ! I ! I t4-4; : J.-~--~-. ~ .~ :44--~LL4-~4_ ........ ',.L . ,_i_L,_, ....... I , · -;~t';' : :'~ i - !' ' il 'i-; i, .-~'.:~.,,'~. ~''r '~ · ,.i ~; ' -- ; ,, il ~, . . i ~i ' ' ''i ' J '' ' ; ' ' ' -~ ' ' ' ' I I ' ' I I I t , , . ~-t_;"~' "'?'"??-~*-~--~.-*+~- ~ ~ -il !--H-i-~ iii ~ , , · , .1 , ' ' J. L Illl ' tit i , i~iJ ,, . ::.; : i t . , ~ ~ , , - ~,. -~, ~ ' ~ . i, ~ il ,~ ~ . ' ,, .. : I ,,. , ~~., ~ ~ T ~ ~ ~,1 ..,,, ,+,, ~, , j~ S~-~-.-,.-~-~-.~..-.-~.4-., ..... ~-. ~ i ; ill , , ,-t'~ / ~/ ~ I , I 1'-~i J-- I t t t~ i , '~.i ! I ' ~ . , : i . IT, ,; , , · I ~ ' ~ ~ ' ' ' i' '' ~ :~/T!I ~[ ~i ~I!i '~ .... MT ~ ii '~l~ ~kr-'~ J , -~+-~--~ ...... ~+~-+-i ~ .It =L.ILM. ~ ~ il I F$. ~S'~W i ~ ~ ~ ~ j ~.i iTFT-~ i i-m--~"~-~'t .... ~l-I"lT--t-'f't+~-t=- ' ' : I ~ I , ' ' ' ~ ! , t j l~- , , ' t '~"~-~I-- *~'-~-~ -' - ' ; ' ~ ] ~ · ~ ~ ~ / · ~ ~ ~ ~_k__~_i._,~ ! I~t I I I / ! 4 1'/1 F i ~ ~ I ['~'q i i i ~W~ "T'l~-,'-'~" 'T'~Te-'t'~-"-t~f"T+'~ 4.-,~--~-~- ~,, ~ i ' ' i i' ~ i iA :~ Mil ', 'H iii! !i R~ ~ ~-lj ~-~-4-! t i ~ i i ~ i i J I [ ~ l ~ ' t i I- J [-fF~"-'~i T~" '~T~-n-t'-ff-~'e '' ~ ~ t i ' . : r : ~ -~-- ~ ..... -.-~ --;~ -~.~_~ .... . ..... ~ ........ ~ _ l,. _, ._ ,~, ,, ~ ..... ~ , ,,,, ;,.i . ..... i · , .... , ~ ' ' ; l ~ ,~,- , N~'t' ~ ,~, , Tt~r , ~. ~~ n-,-~"-: .... ~f4-.P.--~ ..... ~---.-,--~. t , , : . , . . t , ,--- ' ' -- ~'-; ~ ~ , ; i'- -~ I l ~..-~-~+~-~+.-}-' ..... +4-+ .... ~-~ -' , ~ i ;.~ .~ r, . :[~ . . ¢,~ .H- -.~.~ ~ .~ ........ ~ ~ ...... ~ ....... ~ ..... , .... ~.~ ' ; : , : ~- , ~ r , -~r~~~r r---.*~--~ , r~--4 .... +.~ ..... r~.-~.~4-1~ ..... ¢;-~4:-t.--~'t-'~--~~' ~fi~ i , i_~_~ ~i !~ t-~ ~:..,i5-~+~¢~: --~-4~--4 .... ~ i , ~ ~4-M4~ ~ i 1t I i l~, i_lt ; ~ · It I ~-T t i1'~ '-"T','~ ~-~i ~ ~ ;-'r-'--, -~'~ ... ,d-r-,m- ---4- --4 .... ~;.-~: i~ '44~-~ ~-'- ' ~ , L ~, ~' , ~ , I , i ' L I ' ' t ~ ' ~ : - ~ · ~, ~ ~ , ~ ~ ...... ,-4~ ~ ~ , 4~ ...... 4~.--~.~ .......... ~.~_. ........... .,.._ ,,,,.. ~,__.. ~ . 4-, ~-~i~,.~-.~--.~-~ .... ,-. +-~_..~..~.~. .... ,.._~ - - ~ - -- --- -- , · ~ ' ' ' ' ' / - ' , - , ' ., . f,~,, ~--~ ,.;~ ,--, ~, , +¢-~ .-+~-~-q~T ~i.~-~N4-.-,- -~=?.-~.~~..~:.~.'~:~::==4: ...... o ~,oo zooo ~ooo 4ooo 5ooo 6ooo 70'0o 8ooo Pressure - PSIG EXPLORATION AND PRODUCTION RESEARCH DIVISION BP Research Centre Chertsey Road, Sunbury-on-Thames, Middlesex. PETROLEUM ENGINEERING RESEARCH BRANCH /~Ta~ZZ ;, t~ZiZ i!:- ~ ' STATE OF ALASKA COPY Report EPR/R2200 PHYSICAL PROPERTIES OF RESERVOIR CRUDE OIL ~SJ~.-~ES Pm: ~I~3 ~I~?,D, ~. ~o. ~ Work by: P.J. Askins P.A. Read J. S,, W. Wr i'gh t January 1970 Approved by: L.P. Coombes _S_TRI CTLY CONFIDENTIAL -i- Contents Page me Bo Ce Summary INTRODUCTION RESULTS COMMENTS -il- l Table 1 2 3 incl. Figures 1,2 3 4 - 6 7 - 11 Sampling details. Hydrocarbon Analysis~ P-V data above saturation pressure. Specific volumes of Total . { · Fluidin 2-Phase Region.' Differential separation data, 3-stage laboratory separation. Calculated separation data. Sat. Pressure and density (1-Phase). Specific volume (2-Phase). Differential separation data. Calculated separation data. STATE OF ALASKA COPY - ii- S,m~nary This report gives the results of measurements made on samples of reservoir crude oil taken from Put River, Well No.1, and of calculations made for possible operating conditions of the proposed production unit. The samples received were of-upper zone production and combined upper and lower zone production. Both had saturation pressures at reservoir temperature very close to the sampling Pressure of 4,300 psig. Laboratory separation in three stages gave a total gas-oil ratio of 880 scf/b with formation volume factors of 1.37 to 1o39, Calculated separations show that under production conditions a slightly lower G.O,R. can be expected (about 800 scf/b) with a F.V.F. of 1.402. The majority of these results have already been reported to site via Exploration Department, and to ~the Applied Reservoir Engineering Section, Sunbury. They are being re-issued in this report in order to provide a more convenient record of the results obtained to date. STATE OF ALASKA COPY A. INTRODUCTION COPy The first samples of reservoir fluid from the BP Put River area were taken at the end of June 1969, and were sent both to the Research Centre and to Core Laboratories for the usual measurement of physical properties. Results from Sunbury were reported by memoranda to Manager, Production and Petroleum Engineering Division, Exploration Department and to Regional Manager, North America, the majority of the work having been completed by mid-August. The purpose of-this report is to provide a more convenient presentation of the results obtained from both the P.V.T. work and the separator calculations. B. RESULTS Table 2 shows the hydrocarbon analysis of the two samples received. This was determined entirely by chromatography and is in reasonable agreement with that determined by Core Laboratories using a combination of distillation and chromatography.. Unfortunately with a chromatographic analysis no residue is available for molecular weight determination, and the value quoted was calculated from that given by Core Laboratories. Tables 3 to 6 show the normal P.V.T. analysis results including P-¥ relationships at constant composition and during differential separation. At the time this work was done insufficient information was available concerning probable crude oil temperatures, and it is now evident that the temperatures chosen for the 3-stage separation were unrealistic. However, this separation provides a useful basis for comparison of' actual and calculated separations. Table~7 shows results calculated for the same separator conditions, and in this the density of the components boiling above 150°C was chosen to give agreement between the calculated and observed stock tank oil density. · Details of the optimization 'calculations have not been given except for the five conditions of probable interest in Tables 8 and 9. However, the densities of stock tank oil for various combinations of separator pressures and temperatures are shown graphically as the basis on which the optimum second stage pressure was selected. C. COMMENTS Comparison belween the BP and Core Laboratories' results show a satisfactory measure of agreement° At 200°F the saturation pressures measured on the two sets of samples differ by 40 to 50 psi, but since the oil was sampled very near to its bubble point, differences of this order are not unexpected. One of the interesting features of this crude is the low 11 ~ !1 intermediate components content in the analysis (Table 2) as ~compared with typical Middle East crudes. For example the C3 to -- 2 C6 components amount to only 4.5% weight, whereas a Middle East crude might contain 12%. One consequence of this is the relative insensitivity of the stock tank oil density to changes in the conditions of separation. As illustrated in Table 8, a change of 300 psi in the first stage pressure produces a negligible change in the stock tank oil density. However, in the proposed three stage separation system, the second stage pressure does affect the final density and the calculations show that for a first stage pressure of 650 psig and a flow tank temperature in the region of 125OF, 85 psig is the optimum pressure at which to operate the second stage, Another feature of importance is the 4% Wt. of CO2 in the reservoir fluid. This results in CO2 contents of between 15% and 20% in all separator gas streams, and in consequence corrosion problems will be an important consideration in the design of production equipment. Finally, it should be noted that although some adjustment of data has been made to ensure that calculated densities of separated oil are approximately correct, the flash calculations are intended only to show the effect of changes in the operating conditions of the separatars and ~ot as an accurate prediction of final stock tank oil density. CON , "F,!T AL STATE OF ALASKA COPY TABLE 1 .Put River No.1 Reservoir Crude Oil _Sample Data _ Sample No. Sample Date : Shipping Bottles No. : Sampling Depth - ft. s.s. 'Temperature at sampling depth OF : 26th June 1969 386/SS 17 8540 198 Pressure at sampling depth : c4300 Well status W.H.F.P. psig : - W.H,F.T. OF : - Rate B/D : - 29th June 1969 1316/717 8530 198 c 4300 Flowing 1640 67 c 1000 CONFID,')...!.'r!AL STATE OF ALASKA COPY ~ABLE 2 - -. Put RiYer No.1 Reservoir Crude Oil Hydrocarbon Analysis ,i I · Il I I L Upper Zone Combined Zone M. Wts Densities Component Sample 8A Sample 13B Kgs/m~ i ! ~ , ,,. ~' '] ' ' % Wt, % Wt. . i J - --' .... Carbon Dioxide 3.99 4.O0 44 815 Nitrogen O. 10 O. 1 28 568 Me tharm 6 o 31 6.31 16.04 340 E~hane 1.50 1.50 30.1 422 Propane 1 o.31 1.34 44.1 515 Iso Butane 0.29 0.29 58.1 n Butane O. 85 O. 80 58.1 584 Iso Pentane 0.38 ~ 0.32 72.1 625 n Pentane 0.57 0.48 72.1 631 Hexane s 1.15 O. 92 86.2 680 (a) Heptanes 2.09 1.90, 1OO. 2 709 Octanes 3.03 2.88 114.2 739 Nonanes 2.73 2.73 128.3 760 Heavier Cpts.. 75.70 76,43 314 (c) 9i8,2 .(b) ~. ......... , ~ · 100.~ 1OO.OO . . ,1 . . ,, , CONFIDENTIAL ' ' STATE OF ALo SKA COPY (a) Densities are in Kgs/m3 measured at 60°F and with the exception the Decane plus fraction, were obtained from Boiling Point - Density correlations in the BP Data Book. (b) The density of the decane plus fraction was chosen to give calculated flash separations in agreement with experimental separations. (c) The Molecular weight of this fraction was calculated from data supplied by Core Laboratories Inc. (d) The hydrocarbon analysis was obtained by chromatography. TABLE 3 Put River No.1 Reservoir Crude Oil p_oV.,.Data Single~ P. ha.se ,Re~.io.n' 8A (Upper) 13B (Combined) Sample No. , ............ Temperature 80°F 150°F 200°F 80°F 150°F 200°F Pressure ~ Kg/m3 Kg/m3 Kg/m3 K~g/m3 Kg/m3 Kg/m3 psig 4900 795°6 764.4 742°5 798°0 767,9 746.0 4500 793°0 761.4 738.8 796.0 765.1 742.4 4280 - i.j - 736°7 ..... 4270 .... 7~0.3 4089 - 758.1 - - - 4078 .... 761.8 - 3760 - - - 791.9 - -' 3750 788°,.3 ..... · - _ ,tL · , , = ,, . , ~ ~1 1, ,, : - · OONFID; NTIAL Upper Zo,ne~ STATE OF ALASKA COPY At 4,300 psi, density change per OF : 0.46 Kg/m3 thermal expansion at 200°F = 6.24 x RO-4/deg F. At 200°F, density change per psi = .0094 Kg/m3 compressibility at 4300 psi = 12~8 x 10-6/psi.. Lower Zone At 4,300 psi, density change per oF = 0.46 K~/m3. thermal expansion = 6.20 x 10-4/deg F. At 200°F, density change per psi = ,0086 Kg/m3 compressibility at 4300 psi = 11.6 x 10-6/DSi. TABLE 4 .... put R. iv.er. No.1 Reservoir Crude Oil _.S .amp.le 8A (Upper) · S. pecific Volumes .o,~ Total, ~luid Lin. 2-Phase. .. Reg%on 80°F 150°F 200°F Pressure Sp. Vol. Pressure Sp. Vol. Pressure ~p. Vol. P.S.I.A. cu. ft/lb. P4S.~I.A. cu.ft/lb. P.S.I.A. cu. ft/lb. · 3748 o 02032 4104 · 02113 4295 .02174 3667 ~02035 ' 3889 · 02121 4087 . 02180 3482 · 02(]43 3792 · 02131 4019 .02183 3352 .02052 36!7 . 02149 3867 .02207 3247 .02060 3317 .02190 3597 .02247 3057 .02079, 2982 .02250 3267 .02307 2762 ,.~ .02123 2589 ..02354 2937, .02'~)90 2447 .02179 2182 .02534 .2527 .02537 1877 .02382 1752 .02826 2132 .02750 1382 .02813 1322 .03395 1667 .03182 1027 .03458 1042~ .04049 .1272 .03834 779 .04325 827 .04930 985 .04664 583 o 05626 661 . 06031 742 .06024 436 .07421 510 .07664 524 .08474 320 .1007 378 .102~ 407 .1075 232 o1351 277 .1396 296 . ~455 196 .1980 210 .2029 r~-,. ~. - - ~ -. .... _ .... , ..... _ .- CONF[D"Fff AL STATE OF ALASKA COPY ~dO~ VX~V~V ~0 0 TABLE 6 Put River No,1 Reservoir Crude Oil (a) .T.hree S,tag, e Separation Sample 13B (Combined) Stage Pressure PSIG Temperature OF Gas Oil Ratio scf/b Gas Density Kg/m~ Oil Density Kg/m° oAPI Formation'Volume Factor , , 1 6OO 110 611 O.961 2 65 95- 129 1.224 3 0 90 33 1.565 885 28.4' 1.39 (b) .Thre. e Stag.e. Separation Sampl.e 8A (Upper) Stage Pressure PSIG Temperature OF Gas Oil Ratio Gas Density Oil Density scf/~ Kg/m° Kg/m3 OAPI Formation Volume Factor 1 6OO 110 6O4 O~940 2 3 65 0 95 9O 127 40 1.224 1.610 883 28.75 - 1.37 Volumes and densities of both oil and gas are given at 60°F and 14o7 psia~ The FoVoF~ relates the volume of stocktank oil under standard conditions to the volume of reservoir crude oil at 200°F and 4300 psigo CO F!D"F?ITIAL STATE OF A!..^SKA COPY TABLE 6 (Continued) Put River No.1 Reservoir CTude Oil (c) Analysi~s .,of ,Sta~e Gases Sample 1.3B .Comp 0ne.n,t Nitrogen Carbon~ Dioxide Methane E thane Propane Iso Butane n Butane Iso Pentane n Pentane Hexane s Heptanes plus Calculated M. Wt. Calculated SG (Air = 1) Calculated Density Kg/m3 Stage 1 % mol 0.4 15~0 74.6 6.4 2.2 0°2 0.5 O.1 Ool 0°3 O~2 1OO. O 22.54 .778 .952 I IT St.a§e 2 % mol 0ol 2O.O 53.2 14o 1 7.6 0.8 1.7 0.4 0°4 1.1 0.6 1OO. O 27.94 .965 1. 180 S,,t age 3 % mol 0.2 17 .O 24.8 22.O 21.3 2.9 6..4 1.1 1.2 1.9 1.2 1OO. O 37.41 1.291 1.579 CONF!D"' TIAI. STATE OF COPY TABLE ~ ? -- PUt River No. 1 Reservoir Crude Oil 1, Il , · ' ' , · I C_alcu!ated Separation Da.t.a- ,F. or Co. mpariso,n with Table 6 Ji Li i ~1 Il · I ill [ Il I. · · Stage No o 1 2 3 Tempo OF 110 95 90 " Pressure psig 600 65 0 Component Gas % mol, Gas' % mol. Gas % mol. Oil % wt. - . . ..... : _ i , I ,. J I - ,J ii i ... _ il _, __ Nitrogen O. 76 O. 21. 0.03 .03 Carbon Dioxide 15o 23 18.98 13.77 0 Methane 74 o 80 55.59 23.78 . O1 Ethane 6,03 14.37 24.75 .01 Propane 2°05 7o 17 22.73 O. 41 Iso Butane O. 21 O. 75~ 2.89 O. 18 n Butane 0,49 1.72 6.91. 0.58 Iso Pentane 0.09 · 0,28 1.21 ' 0.32. n Pentane 0.11 0,35 1.48 0.51 Hexanes O. 10 O. 27 1,14 1.11 Heptanes O, 08 O. 19 O. 82 2.23 Octanes O. 04 0.O9 O. 38 3.38 Nonanes O.O1 0,03 O. 11 3.16 Heavier Cpts O 0 O 88.O7 - . ....... .~ 'lift , i 1111[ ! - . .. . ~ - .- .- , ' i' ~ . . Il , 1~o: oo. lo°. oo loo. oo loo. oo · . . GoO.,Ro scf/b 602 142 32 - Density Kg/m3 .947 1. 151 1 °578 884.8 Molo wt, 22,41. 27.25 37°36 - · SoGo (Air=l) .774 .941 1.290 - . , , ,( REF. No. AFS 1315 BOTTLE 700 710 720 730 PUT RIVER No.I RESERVOIR CRUDE OIL (COMBINED) No. 717 740 750 760 770 DENSITY- K g / m3 .CONFIDENTIAL 4900 480O 4700 4600 4500 4400 4300 4200 4100 4000 3900 3800 780 790 3700 BO0 · PUT RIVER No.I RESERVOIR CRUDE OIL (' PPER)' .~REF. No. AFSSA ' I. IllllJliltl'lllll] J~Jli'l ] Il'il'Ill ~111'11 I'llllllll I' JJJJJJ!llljlllljjjJJJ Il! JJ I llll Ill Ill! I lllll ] Il Ill ll Il. I_ ;., Illlll ill Ill Illlllli II I. Illl ' 1111 l[lll Illll!l lllll illll-Illl ! ]lllJl : II[lllllllllltl. j!j ,,ljifiijj llll..t.I lllli'll ,,1,, ~ ,fi. Il,,, ! ,il,,I iiiiilli]lllllli. 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Jillllllllll LI ] I.I1111111tlttt1.1111 lJlll ',.Ill'Ill IIIitl [tiiiit.II , il ~ ~1: Illil:lllllltltlll J. 1t~1111 'itlltl I. Illlll.lll 11:1~'t'- IIII1111.1111111l L: lllJllllllltllllJ-I I~1'!!1 ri IL.l,,lllll]llllllJll[l IJlll .JJJ.J. ll.. 11[tll irlltiJllll' P. : t. llt~l:'i jJlltllJlll.ltlll '';,' ..ll'Jl.tllllllttl ]JJJJJJ 11~'t11~ 1't.11.1.1 t.l. llilll~ . i IIl. ll'~ Illillillll:lll~[ 1.1.t11.1'1.11111ttlltjl II111 .J. lll. lJl' l.l'l, lll~i 'ltlJl'ltlll', IJlllt~ I!111111111111J! I/lllllllllltl.ll. JlJ I11.11]jllJll. Illlll.. .IIIIlJllll. '[ ltlllJ ~ lill.lllll-'lllllll :illltllt.lillllllllt .I.[.1:!11 Iltlt. I. IIIIIl..J It11~11;I !1111I ~11111111111111L~ r .ll.l'llllll.lll. Jti.tll- IlJlJJ I11111 lil~ll ' I11I[1111 I lttl't'! '~ll[li:lllfllt.it.l I[lll.L. JJJ. JlJ[JJ~.lt 11tll Iil1'11 Illlll ] 11111I~11' i;lil]l t~llli.[llillllll I r~llllll..[ltlllllllll. I II11t[ JJlJll I'tllll. ll[l]ll, llllt JJ. Jllil IIII.!1 I I. Iit'11 llllllllll I 'It~1111 ll-~Jlllll.ltll. JtLi I [~'"llllll'li~llllll[[J'~ 1'1111.11 Itli. II I'IIL[I J iltltI'lllr'r · illlfll l[J~llllJJltllllJ I.l.lllll.Jll'llJJ'JJ.lltI ]fill.it Il. Ill.[ ~. lll. fll ~ Illllllll ~ Jl.itlli[ rllll~lllllllllllL [llll. Jl.].[{l.!~lli llllllJ J]~l!! .I. Jillll .ltlifllll i l ll'!tl.ll. IIII,TilIItlIIII 'i .llllltl'll'llttll l'l' t.t. tlrl: l'lllll ~ Iltltl. '~ ]111111.1_[1I' I Illlll[.rtlllltllltll.lllL [llllllllillJllll't I.II!11. III.Ill III111 Ilt111'III I ,!i11111 !!11'11.111I~!1'{~ 'llllll'lllllltllltl J. lJl[' ' Illtit. Illtll ' !1[1111']1.1 I i11111,,,,.~lllllJJl II -JjJlllllll[llll. Jl II11.1.1..~ I1.11.11 I11't[1 ! l[.Jlllllll' -I ~1111tl IIIIIIIl,'Jtlllltl .STATE OF ALASKA..COPY BOTTLE No. 38E 4900 770 780 790 :S.P. ! 480O 4700 . 4600 45'00 4400 430.0, 4200 4100 4000 390O 3800 37.00. 8O0 FIG. 2 ] REF. No. AFSSA SAMPLE Ne. 386 PUT RIVER No.I _ASKA, CO?Y 4000 300O 2000 I000 900 '800 700 I I 500 400 300 200 '02 · 03 · 04 · 05 .06 -07 -08 -09 .10 ~I)F. CIFIC Vt~LUMI;-- cu_ f.l:./Ib .15 .20 PUl' RIVER No.I (--.s~vo,. c,u~ o,. (cor'-,.~) REF. No. AFS 13 B BOTTLE No.717 DIFFERENTIAL SEPARATION. DENSITY OF .SATURATED OIL. 860 840 830 820 :810 1800 790 78O 70 0 750' 0 i000 2000 3000 4.000 PRESSURE -- p.s.~.g. 740 .5000 FIG, PUT RIVER No.I (:" RESERVOIR CRUDE OIL (, .COMBINED) REF. No. AFS 13B BOTTLE No.717 DIFFERENTIAL SEPARATION. RELATIVE VOLUME OF SATURATED OIL. I-0 0-9 :~ ' O O 0 . I000 2000 3000 PRESSURE - p.s.i.g. 4000 0.76 5000 PUT RIVER No.I ( RESERVOIR CRUDE OIL (..COMBINED) REF. Ne. AFS 13 B BOTTLE Ne.'717 DIFFERENTIAL SEPARATION. GAS--OIL RATIO. I000 90O 800 0 700 600 u~ 500 I 0 400 - 300 ..I 0 'o · I00 I'000 2000 3000 PRESSURE -- p.s.i.g. ..~.. ~, .- ~, ~.. · 4 000 0 S. O00 EF. No. AFS 13B FFERENTIAL SEPARATION. VISCOSITY OF SATURATED OIL . RE ,<VOIR CRUDE OIL '["COMBINED`) ~ z--z~ BOTTLE N~'.717 6000 $000 4000 3000 2000 I000 2-O -3-0 .VISCOSITY--CENTIPOISE 4'O O 5-O FIG. 7-1 PUT RIVER No.I [ RESERVOIR CRUDE OIL CALCULATED 3 STAGE SEPARATION- OPTIMUM 2ND. STAGE PRESSURES V IST. STAGE PRESSURES AND TEMPERATURES. 7O0 ~oo ~, soo ~' 400 300 ISO 140 130 ,,, 120 ~ uJ I10 m I00 u~ 50 60 70 80 90 . OPTIMUM 2ND. STAGE PRESSURE-- p.[i.a. 90 I00 STOCK OIL S.G. V STAGE I PRESSURE AND TEMPERATURE. (OPTIMUM 2ND. STAGE PRESSURE). 150 140 120 ,,, .I-- I10. I00 90 · ',B84 - 0-885 0.886 0.887 0.888 STOCK TANK OIL DENSITY-Qms /cc ('60° 700 soo 400. uj ao 0.889 PUT RIVER Ne.I ( RESERVOIR CRUDE OIL CALCULATED 3 STAGE SEPARATION. I ST. AND 2NI~. STAGE GAS OIL RATIOS. 700 ,, i 650 c~ 600 uJ 550 200 150 40 50 60 . 70 80 STAGE 2 PRESSURE -- D.s.i.c~. 90¸ I00 p.s.i.a. PUT RIVER No.'l ESERVOIR CRUDE OIL ~CALCULATED 3 STAGE SEPARATION, FLOW TANK G~O.R. V STAGE 2 PRESSURE. 40 30 20 I0 40 ,, I 'r~ ~0 20 ~ 0 I0 40 30 ~ 20. ?~'_- 4O 5O 60 70 80 STAGE 2 PRESSUR.E-p:s.i.a. 90 I00 .FIG. II 'l Company BP Alaska Inc. Well BP. 27 -'11 - 14 Field CORE LABORATORIES, INC.(' , Petroleum Reservoir Engineering DAI. LA$, T£XA$ December 27, 1971 Date sampled.. County. State Page. 1 of File. RFL 7309 ..June 12, 1971 Alaska Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas-Liquid Ratio Production Rate Separator Pressure and Temperature Liquid Gravity at 60° F. Datum Elevation Total Depth Producing Interval Tubing Size and Depth Open Flow Potential Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge FORMATI~)N CHARACTERISTICS Shubtik Limestone WELL CHARACTERISTICS SAMPLING CONDITIONS PSIA o F. Flowing Tubing Pressure Flowing Bottom Hole Pressure (8310 Ft. ss) Primary. Separator Pressure Primary Separator Temperature Secondary Separator Pressure Secondary Separator Temperature Field StOCk Tank Liquid Gravity Primary Separator Gas Production Rate Pressure Base Temperature Base Compressibility Factor (Fpp) Gas Gravity (Laboratory) Gas Gravity Factor (Fg) Stock Tank Liquid Production Rate ~ 60° F. Primary Separator Gas/Stock Tank I,iquid Ratio or Core Laboratories, Inc., Engineer PSIG @ PSIG ., 19 Ft. SCF/Bbl Bbls/Day °F. °API Ft. Subsea Ftc Ft. 8382-8398 Ft. ss In. to...Ft. MMSCF/Day 4247 PSIG @ 8316 Ft.ss ., 19 , 195 o F.@ Ft. 424 (75, r. ) PSIO 890 PSIG 2 50 PSIG 113 °F. PSIG °F. 53.2 o API ~60°F. 4000 MSCF/Day 44. 7 Rbls/Day 89500 ..... SCF/Bbl .Bbls/MMSCF REMARKS: CONFIDENTIAL STATE OF ALAS <A COPY These analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for 'whose exclusive and confidential use. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted): but Core Laboratories. Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion. or profitableness of an}' oil. gas or other mineral well or sand in connection with which such report in treed or relied upon. CORE LABORATORIES, !NC. Petroleum Reservoir Engineering DALLAS. TEXAS December 27, 1971 Page 2 of RFL 7309 Well BP 27-11-14, A FS 90A ASTM Distillatibn of Stock Tank Liquid Gravity = 51.7° A PI @ 60° F. Percent Temperature, o F. IBP 134 5 184 10 206 20 ZZ7 30 252 40 274 50 294 60 3ZZ 70 355 80 414 90 508 94 EP 581 Recovery 94.50/0 Loss 0.0% Re sidue 5.5% STALE OF ALASKA COPY These analyses, opinions or inte~a~retations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpret,-t'tions or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted): but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion, or profitableness of any oil. gas or other mineral well or sand in connection with which such report is used or relied upon. Company Well CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS December 27, 1971 Page, 3 of File RFL 7309 Field BP Alaska Inc. BP 27-11-14, AFS 90A Formation County Shublik Limestone State Alaska HYDROCARBON ANALYSIS OF Stock Tank Liquid SAMPLE COMPONENT MOL PER CENT. WEIGHT PER CENT DENSITY ~ $0e F. e AP! MOLECULAR GRAMB PER CUBIC ~ 60° F. WEIGHT CENTIMETER Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes Octanes Nonanes Decanes Undecanes plus Nil 0.01 Nil 0.01 0.08 0.60 0.40 1.70 1.36 2.34 9.29 14,23 22.16 15.41 11.21 21.20 100. O0 Nil Trace Nil Trace 0.02 0.21 0.19 0.80 0.79 1.37 6.46 10.37 19.73 15.71 12.60 31.75 100. O0 0.7373 60. Z 90 0. 7632 53.7 110 0.7801 49.7 126 0. 7921 47.0 139 0.8291 39.0 185 Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manager CONFIDrNTIAL STATE OF ALASKA COPY These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential rise, C~oiS re.p~.rt i.s m. ade; The in?.rpre~.tions or .opini2ns expressed represent the..,b~..t jud?men, t of Core Laboratories, Inc. (all errors and omissions excepted): but re baoomtorles, inc. aha 1ts omcers ann employees, assume nO responsioili~y ann make no warranty or representations as to the productivity, prolaer opera° tion, or profitableness of any oil, gas or other mineral well or sand in connection with which such report Is used or relied upon. Company BP Alaska Inc. Well BP 27- 11- 14 (Rate B} Field CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS November 5, 1971 Date Sampled County. State Page 1 of File RFL 7308 June 12, 1971 3 Alaska FORMATION CHARACTERISTICS Formation Name Date First Well Completed Original Reservoir Pressure · 0riginal Produced Gas-Liquid Ratio Production Rate Separator Pressure and Temperature Liquid Gravity at 60° F. Datum Shublik Lime stone , 19 PSI(] .SCF/Bbl PSIG Bbls/Day °F. API .Ft. Subsea WELL CHARACTERISTICS Elevation Total Depth Producing Interval Tubing Size and Depth Open Flow Potential Last Reservoir Pressure Date Reservoir Temperature Status of Well Ft. .8382-8398 Ft. ss .In. to Ft. , MMSCF/Day 4247 ' PSIG @ 831.6 Ft. ss , 19 _ 195 °F.@ Ft. Pressure Gauge SAMPLIN(] CONDITIONS Flowing Tubing Pressure Flowing Bottom Hole Pressure (8310 Ft. s s) Primary. Separator Pressure Primary Separator Temperature Secondary Separator Pressure Secondary Separator Temperature Field Stock Tank Liquid Gravity Primary Separator Gas Production Rate Pressure Base Temperature Base Compressibility Factor (Fpv) Gas Gravity (Laboratory) Gas Gravity Factor (Fg) Stock Tank .Liquid Production Rate @ 60° F. Primary Separator Gas/. Stock Tank Liquid Ratio or Core Laboratories, Inc., Engineer PSIA o F. 424 (75 0 F, ) PSIG 8 90 PSIG 2 5 0 PSIG 113 oF. PSIG °F. 53. Z o API@ 60°F. 4 000 , MSCF/Day 44.7 89500 Bbls/DaY SCF/Bbl .Bbls/MMSCF REMARKS: Separator gas samples AFS 88A and 88B, 89B. separator liquid samples AFS 89A and. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom. and for whos~ exclusive and confidential use. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted): 'but Co~ Laboratories. Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, p~'oper opera- CORE LABORATORi~, INC. Petroleum Re~er~4r E#g'~,eeri#g' DALI.AS. TEXAS November 5, 197]. Pa~e 2 of, File RFL 7308 Company BP Alaska Inc. Formation Shublik Lime stone Well B P 2 7 - 1 1 - 14 (R ate B ) County. Field State Alahka ' HYDROCARBON ANALYSIS OF AFS 88B Separator GAS SAMPLE COMPONENT I MOl. PER CENT ] G P M Hydrogen Sulfide Nil*. Carbon Dioxide 12.16 Nitrogen 0.6 3 Methane 76.93 Ethane 5.4Z 1. 365 Propane Z. 50 0.686 iso-Butane 0.36 0.117 n-Butane 0.85 0.26 7 iso-Pentane 0.23 0.084 n-Pentane 0.31 0.112 Hexanes 0.26 0.10 6 Heptanes plus 0.35 0.158 100.00 2. 895 Calculated gas gravity ( air = 1.000) = 0.76 9 Calculated gross heating value ---- 10 Z 9 BTU per cubic foot of dry.gas at 14.696 psia at 60° F. Collected at 251 psigand 113 OF. Sample AFS 88B opened at 250 psig in the laboratory. Sample AFS 88A opened at 8 psig in the laboratory. * No reaction with lead acetate paper. CONFIDENTIAL STATE OF ALASKA ..Ti?ese analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, tflzs report is made. The interpretations .or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers 'and employees, a~ssume no resPOnsibility and make no warranty or representations as to the productivity, proper opera. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS November 5, 1971 Page 3 of 3 File RFL 7308 Company. Well., BP Alaska Inc. BP 27-11-14 (Rate B) Formation. County Shublik Limestone Field State Alaska AFS 89A HYDROCARBON ANALYSIS OF Separator Liquid SAMPLE COMPONENT MOL WEIGHT DENSITY (~ 60e F. e APl PER CENT PER CENT GRAMS PER CUBIC ~ 60e F. CENTIMETER MOLECULAR WEIGHT Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus Nil Nil 1.83 0.73 0.04 0.01 5.64 0.81 2' 00 0.54 2.47 0.98 0.83 0.43 Z.61 1.37 1.60 1.04 Z. 72 1.77 9.34 7.23 70.92 85.09 0. 7897 100.00 100.00 Collected at 251 psig and 113° F. 47.5 133 STATE OF ALASKA COPY Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manage r These analyses, opinions or interpretations are based on observations and material supplied by' the client to whom, and for whose exclusive and confidential use, this 'rcpo~ is made. The interpretations or opinions expressed represent the best Judgment of Core Lal~ratories. Inc. {all errors and omissions excepted); but ~ ~EOLOGIC/TL ~'~_~A~a~ =603 ^RCT,C 80UL£VA.O ANCHORAGE, ALASKA 99603 WATER ANALYSIS REPORT ; OPERATOR BP Alaska, lnc, ' . WELL NO. 27-11-14 FIELD North Slopq. COUNTY , STAT~ Alaska I. i REMARKS & CONCLUSION8: DA?~ Jun~ 11:1971 _ ~ NO- A 944_ LOCATION FORMATION.. Sadlero~hi~ . · INTERVA,. 8~08~.- 851~' BKB ...... 8AMPLE IzRO~ Separator ..... Cloudy oranMe water, irpn.oxide present, ....... i produced-'water, zas rate II ' Sample taken May 30, 1971. i ii I I I , , · ~xUum ...... 641 ~ C~um ...... ., , 17 0.85 ~ ....... Pl~n~: --- Total diaaolved ~ meal ..... , 1629, ,. NaCl eqai~mlent~ m~/l ...... . . . 1411 0~. pH .......... ., 5~., 9 t ~ [ L i t [ [ , [ 111 , , 8pec~ recatamce ~ Obf~rved .... . 3,98 Ha Mg .... OF ALASKA COPy S~ple above descfib~ MEQ ~ U~t Ct'- 10 Na HCO~ -1 Ca SO, 1 Mg CO = 1 Fe. CI HCO3 SO~ COs ( 2603 ARCTIC BOULEVARD ( ! ANCHORAGE, ALASKA 99603 · · 'WATER ANALYSIS REPORT = OPERATOR .-BP.Alaskar Inc. DAT~C June 11, 1971 MD NO. A-944-2. '~ WELL NO- 27-11-,14 LOCATION · '~ . · ! FIELD North Slope ~ FO2MATION Sadlerochi~ i COUNTY ........ INTERVAt 850 8 ' -.,,, 8514 ' BKB '' STAT~ Alaska 8AMPLE FRO~ Separator RRMARKS & CONCLUSIONS.- Cloudy orange water, Iron oxide present. Produced water gas rate III Sample taken M. ay 31:19.71 . . . i , i i i it i 584 ,, Poitultm ..... 2Q _ . O. 51 Ctlcimn ........... 17 0.85 ' Magn~um ..... q"r'a ee . --- Zro~ ....... Present , --- . · · I [ Ill [ I I _ . 25.40 · {. To~l Ca~o~ .... 26.76 : ; . i I i , , - Toud d~o~ed ~ n~/: ..... 14~0 NaCI ~m% ~/1 ...... . _ _1254 O~ pH ' '* 5 R 8ulta~ . . . .... 0 Chlorl~ ....... ' 360 0 Blctrbonat~ ..... 1013 - Hydroxide ..... 10.IS L ' 16.61 _ _ I J I J Il Il 8p~dflc mlsm ~ 6~'~.: Obrarv.d .... 4.9'0 oha-zza~ · . 8ample above described MEQ p~r.Unit ,, , 10 1 Ca 1 "Mg Fe CI HCO3 SO,~ CO~ DATE TO Mr. $. W. Kingsbury OFF,CE Anchorage, Alaska FROM OFFICE YOUR LETTER FILE Letter No. SUBJECT Porosity and Grain Density, Put River State #l MY FILE May 14, 1970 P. B. Morris~ Chemical Engineering PRC Piano, Texas, E133 00-393 Attached are Boyle's Law porosities and grain densities measured on perm .plugs from the Put River State #1. All perm plugs were still available, so new porosity and density values were obtained for each of the plugs. . Porosity was determined as described in my letter of May 6 to the Reservoir Engineering Subcommittee. Grain density is expressed as the ratio of dry weight to Boyle's Law grain volume. , P. B. Morris sj Attachments cc: Mr' F. G. Baker Dallas, texas Mr. Joe Stoll Los Angeles, California CONFIDENTIAL -223 PLEASE CONFINE EACH LETTER TO ONE suBJECT ?IJT }<IVER STATE /! 1 CO RE NO. 1 /J' 6~/ GRAIN DEPTH PO R- DEN · FEET PCT. GM/CC 9006-07 25.8 9007-08 21. 7 900,3-09 21.7 9009-10 22.6 9010-1'1 23" i- 9011- 12 22.4 9012-13 20.~ 9013-14 25.8 9014-15 27.4 9015-16 23.6 9017-18 14.8, 9018-19 13.9 9019-20 21 -8- 9020-21 21 ,'~'~ '9 021-22 22.8 9022-23 23,3 9 023-24 26, ? 9024-25 25,2 9025-26 26.8 9026-27 23,8 9027-28 23.0 . 9 028-29 23,9 9029-30 23.9 9030-31 '~3, 4 9031-32 25.6 9032-33 26'3 2.66 2.70 -2.70 2. 77 2.73 2.70 2.74 2.71 2.64 2.66 2.67 2 · '67 2,65 2,64 2.67 2.64 2.64 2.63 2.62 2.65 2.66 2.66 2-65 2.64 5.64 2.63 CONFIDE*' PUT RIVER STATE CU R,E NJ · 2 GRAIN · DEPTH P,gR. D EI'.~ · FEET PCT. GM/CC 9040-41 27,S 9041-~2 27,7 9042-43 26,8 9043-44 27.7 9044-45 25-5 - 9045-46 19.9 9046-47 23.9 9047-45 22,5 9 04S-49 25.7 9049-50 26. l 9o5o-51 ~5"2-' 9051-52 26.9 9052-53 21.4 9053-54 22.2. 9054-55 24,4 905'5-56 21.0 9056-57 23.8 9057-5S 22./1 9055-59 17.5 9 o s 9- 6o ~ 9060-61 19.5 9061-62 16.4 9062- 63 24, 7 9063-64 24.8 9064-65 24,3 9065-66 26.4 9066-67 25.2 9067-6~ 23.5 9 068- 69 23.7 9069-70 26.0 9070-71 25.2 9071-72 24.5 9 072- 73 23.5 9073-74 22,8 90?4-75' 21.3 9075-76 21.7 9076-77 25. 1 9077-78 24.4 907~-79 23.7 9079-80 25. I . 90o0-"10 24.3 9081-82 21 · 5 9 052-83 21.7 9 0<J3-$4 18.5 9 Of 34-L~ 5 24.8 9 0."~ 5- S 6 22.9 90g6-[~7 17.9 9 037-85 2'2. 7 9 0~3-$9 23.4 9039-90 26.2 9090-91 ~6.9 2.63 2.63 2.65 2.64 2.65 2.69 2.77 2.66 2.66 2.65 2.66 2.66 .2.69 2.65 2.65 2.67 2.66 2.67 2.67 2.68 . 2.67 2.66 2,73 2.70 2.79 2.65 2.68 2.68 2.68 2.69 2.67 2.66 2.71 2.72 2.91 2.$1 2.70 2.68 2.69 2.6~; 2.64 2.67 2.6') 2.66 2.65 2.69- 2.$1 2,6'2 2.&7' 2.65 2.62 P N I V'ER C:3 RE ~9 · STATE 4 PUT RIVER STATE # Cci RE N9 · 3 DEPTH POR, FEET PCT. 9092-93 9093-94 9094-95 9095-96 9096-97 9 097-98; 9 071~-99 9100-01 9101 -02 9 tO 2-03 9103-04 9 I04-05 9105-t)6 9 106-07 9 lOT-OS 9 t Os-09 9109-10 9110-11 9111-12 9112-13 9113-1/4 9114-15 9115-16 9116-17 9117-18 9115-19 9119-20 9120-21 9 121-22 9 1 ~o 9 123-24 9 124-25 9 125-26 9 126-27 9127-23 9 128-29 9 I29-30 9130-31 24.3 23.2 22.3 22.3 22.4 24.4 23.8 22.1 23.9 18.6 18.0 18.4 14.6 23.5 23.3 23.1 9,0 20.5 37.1 27.3 24.9- ,. 23.9 25.5 24.7 24.2 24.3 24. 1 25.3 2t.6 22.0 23.3 22.4 21.? 15.2 18.4 17.2 18.0 19.0 GRAIN DEN. GM/CC 2.70 2.68 2.75 2.74 2.81 2.66 2.66 2.77 2.65 2.78 2..69 2. 68 2.71 2.72 2.80 2.77 2.74 2.77 2.67 2.65 2.66 2.67 2.6.5 2.71 2.70 2.71 2.67 2.75 2.69 2.87 2.76 2.73 2.77 2.87 2.68 2.74 2.75 2.72 CON FIDENTIAL DEPTH FEET 9131-32 9 132-33 9 133-34 9 134-35 9135-36 9 I36-37 9137-38 9 13,3-39 9 139-/40 9140-~1 9 1/41-42 9 142- 43 9143- 44 9 144- 45 9 145-46 9 146-47 9 147-48 9 148- 49 9 149- 50 9 150-51 9151-5.2 9 152- 53 9 153- 54 9154-55 9155-56 9 156-57 9157-58 9 158-59 9 159- 60 9160-61 9161-62 9 162- 63 9 163- 64 9 164-65 9 I 65- 66 9166-67 9 I 67-68 9 16F$-69 9 169-70 9 t70-7i 9 171-72 9172-73 9173-74 9174-75 9175-76 9 176-77 9 177-7g 9 173-79 9 ! 79-30 9 1S0-131 91S1-8fi POR. PCT. 16.7 19.8 24. 1 25.7 25.9 25.4 24.4 25.3 25.1 23.0 24.7 17.1 20.~ 23.0 23.0 22.2 24.5 22.3 25.1 18.4 22.6 22.3 22.? 24.4 24.7 24.6 22.0 23.9 25.5 24.5 23.0 24.1 24.6 I?03 20.1' 23.8 23.0 26.2 24,4 22.8 24.3 25.6 21 .~ 20.7 24.4 24.0 23.5 24.~ 25.4 27.4 27.0' GRAIN DEN. GM / C C 2.77 2.66 2.69 2.76 2.6'-5 2.72 2.70 2.70 2.67 2.72 2.75 2.65 2.72 2.7-4t 2.78 2.67 2.75 2.70 2.68 2.65 2.68 2.64 2.74 2.67 2.69 2.76 2.S2 2.72 2.65 2.79 2.78 2.76 2.64 2.65 2.69 2.70 2.79 2.68 2.68 2'.65 2.67 2.66 2.75 2 79 2.63 2.70 2.68 2.70 2.77 2.6S 2.68 C 9 ,,"J '[ I N IJ E D PUT RIVER STATE C"J RE N~ · DE I>TH P3 R. FEET PCT · 91 :"32-83 25° 5 9183-84 25. I 9184-8.5 26.4 9185-86 26.7 9186-87 26.9 9187-85 24. 1 9 185-$9 24.7 9 1S9-90 25.~ 9~90-9~ 919~-9~ ~3.7 9 192-93 24. ~ GRAIN DEN · 6H/CC 2.74 2.77 2.73 2.70 2.69 2.70 2.72 2.74 2.71 2.80 2.72 PUT RI VEP, STATE CgRE NO. 5 DEPTH P'3 R. FEET PCT · 9193-94 9194-95 9195-96 9196-97 9197-98 9198-99 9199-00 9200-01 9201-02 9202-0,'3 9204-05 9209-10 19.0 22,1 20.0 20.7 18,1 20~3 20,8 19.8 20.2 21.3 26.0 24.0 5.8 GRA IN DE:~. GM/CC 2.69 2.66 2.67 2. 71 2.67 2,76 2.71 2. 69 2. 68 2. 69 2,64 2.67 2.80 CONFIDENTIAL ~ ~olo ~o?o /6 /¥ /& fl. 0 d~/D~ /£ · 0 0 -'r/ ~ ! I · · · · OOo oo oo oo oo oo oo. ee .* ~J ~ ,4-1, 4.-~ O0 , '00 leleeeee leele~ee 00000000 88ooooooo°° ~ . :: i I I I I i i , '! OPERATOR INCORPORATED- 1870 Chemical Engineering Group (P. E. Lab) CORE ANALYSIS DATA--"PLUG ANALYSIS" , ' COUNTY ~?-I0.-,. Iy. STATE ,,, FIELD OR LOC CORJNG FLUID CORE TYPE & DIA. HOW PACKED: J-J Sealed C] Unsealed C4 CORE NO. FERMEABIUTY COLOR SATURATION RECOVERY POROSITY MD. INDEX % FORE ,SPACE CHLORIDES D E · DEPTH % Horlz. reft. NO. ' O11 Water ppm ii ~o~,~. ~l'~'--~oot,-~.~ co-,. '~,~ ~.~.,. ".'~' . ,-. ' .,~, ,.' .~:, - .. Ii - I [' t 1 o '. .. I · .,. , . ~/ It- 13 .' 92.~. "; ' 15.8~t,$".':'"" ~t. i? -18 ~ ~.~ "?:"' '"":'-" '. ,,, ,, , , , , ,,, i , ,, , , i i , , i i i ii ii , , , , , ,, ,, , ANALYST NOTES, DI~B~ION DA~ REPOR~D ....... DATA ~F. CONFIDENTIAL' .:, , .. ., ; ., Chemical Engineering Group (P. E. Lab) CORE ANALYSIS DATA--"PLUG ANALYSIS" ~' COU~ FIELD OR LOC. , ,- CORING FLUID .... ' ..... · CORE TYPE & DIA, HOW PACKED= f-i Sealed [:] Un~aled "'~-"~~'~~_ m i i ii ii i · CORE NOo PER/~EABILn~ .COLOR SATUIIATION RECOVERY PO~S~ MD. IND~ ~ ~ SPACE ' C~~ DESCRIPTION l DE~H ~ Ho~ Ve~. N~ 0;I Water.. ' ~ i ii .i i i i ii . . '~' ~.;' ~: : · .... "s~' " lu,8 M.~ .,e::,~.s...' .._ - t 3 ~o , -:";' '" I O.~ '..~,[ ::77.~,,:~-.:-.::-.'-:::, , .: -- -' ... 3~- ]3 380 ':...'::.:~'-': ~'~':" ::" lS.( '~s.~ '?~..~.'--".~'. :'.'. ~~,-:'.~..-'.'..-'..:, ..'. .... '"' ':':~'~:~':" '" """ ' ':-"":::'""" "' ..-' ,.L"' .' '' · "'..,. ... ,. " ,-. :. ,?. , ~"' · .',.",';,.'=':..~ .. ' . .;~.;.',..~.,.~ ,.,.:. ',: .; ·: ~.. - ...~ .. , . ~. ~~- ~t.. ~,~ 3~o '-..'::.,':...::..... :' : :. · ILl . ~?.C, .~:':::;;::'-~::::~::'.?;.';:',~,,.:. .,......:,.,.: r~k ~, ~&Q,. ~.~;. ' ', '.-'. i /:~;:',..:. ~4,' ~ : ~,/ ~. , ' ~ / :'./:' :-; ;" 'i' . : , i i iiii, iii mi i i i i i ANALYST NOTES: ~ ~Avy / ~f~?l~ ~ I~ DI~B~ION .,.. · DATE REPOR~D CHECKED BY A N O S o~ ~- 8 [., ., r, , ~~KI ~i ~.~ KIT! A '1' '':::,~ ~ ~ '"""::'". '~,. . ,,:. . . ~PROVED "* OPERATOP C, 0 Chemical Engineering Group (P.E. Lab) CORE ANALYSIS DATA--"PLUG ANALYSIS" ........ : COUNTY .... CORE TYPE & DIA- fiELD OR LOC. C ~TATF '* HOW PACKED, O Sealed '* C] Unsealed " .......... *"-'~"~*.._.~. COi~NG FLUID i ii i CORE NO. PERMEABIMIY COLOR SATURATION' RECOVERY POROSITY MD. INDEX % FORE SPACE.. CIILOPJDI~ D E $ C R I P · I O N · DEPTH . % Hor;z. Vert. NO. · O;! Woter ... 'ppm i i i I -,, ·, ii iiiiii i '' '.~ ~' ;. '~";)Z-~:.' "::t~ ',~ · (~- ~ .. 8o,$ ,~,~'?::';"?.' 30,0 ~8.~ -.,,-? .... ~,, ...... ,: ~~ .:?::';,~',:"~ ".. ':'-" G8 - &~ 88.6 ::r::~'." ~e. 3'~(.~. ~- ~t ~'4.t ~ 1 80. 3~.~ 3~.e ' "~ i i i i i ii i i i e i iii i1'1 i i i ANALYST NOTES~ ' DI~B~ON DATE REPOR~D . '. DATA ~F. . - .... .. ~ ', .. ° '"'* ~ ~" ° * · OPERATOR , ~' O .... Chemical Engineering Group (P. E. Lab) CORE ANALYSIS DATA--"PLUG ANALYSIS" , 'COUNTY , , CORE TYPE & DIA, C '' [~ Unsealed FIELD OR LOC, CORING FLUID .......... I-! , ,, Jl I , I Ill Ill Il I Il I I U 11 Il II I coR~ ~o. PE'~r:~s~Lrn' COLO~ S~T~T~O~ ~ .. .~cov,:.Y PO.OSr. ,~D. ' ,.~,~x ~ m~ sp. cE ~o.D.. o Es c RI PTI o. . ~'" ~ ~,.o,;~ .,,"v;.. ,, ,o.. 'o, w~., :.'~,~-~ .... - ., . i ,,, ,. i,, ii i i i i i i i ii iiii i i ii i i i i i i ,,1 i i . ANALYST NOTES~ Di~B~ON .. DATE REPOR~D ........... . . .. DATA ~F. ,. , OO N FI D E NTIAL .~ ~..'.:., .. · . ,.~.- ....... · .......... ::ii ..... ' ............ Chemical Engineering Group (P.E. Lab) ......... ,' ' ' CORE ANALYSIS DATA--"PLUG ANALYSIS" ~ ! i i iiii i i i iii i i iii ii ii .. : .....~. · OPERATOR C O COUNTY_ CORE TYPE & DIA · · i i i ~s, & ~L 10. ;' l~,v ~ c~.r -r~ '11~-~ ~^TF ................... .,,.ow ~Ac~., o s.~o, 0 Un~l~ FIEm OR LOC ..... - , CO,NO FLUID , ', , , 0 .... ~ . ± i ! i i i i i ii i ii i i i i CORE' NO. PERMEABILIIY COLOR SATURATION i '- RECOVERY POROSITY MD. INDEX' % PORE SPACE ."CHLO~JDE~ DESCRIPTION -. , ii ,, ,1 DEPTH Horiz. Ye/t. biO. O;I Water · , ii i i ii ii i i i i oK~ #3 0o9~.~ ~l~ 04 ~:',~,r....3 ILS' l~,:, 38.~' --~.:-.,:..._....:...~...~... :~':...'-, I' .~ ... e3- 9~. i:a.~/, t,o :".' :' ': :.,.?!'i.:'. '":..;.': :. ;s,~, '~zs. :"T:':'!({.i.:;.:-',." $~~,':::..i,.[: ' -'-:. ' · ~;'.:~:~!'i;,:%. :,:.,i'..:~.t':-. '.¢.~' 904 i!!::.iU:.~.i:,i:f; 'D:::).::..:: .*~ . 's~.l, .:....~,.,?..,.;:.:...,..:.. '~a~r,. (:' ..'." .,. _...: :.. · .: . ' ,9/:, - 91 11. I/. "I~ o. ; ."..'~::.":,,'~:.'-;-?' :?.'.' .' . ?. . .., ,,~, ~/~,[:,,. ,...: .. I.. ,~$- 9~ .1 :":~-..-':.':i:'}ii:;'. ':':i:::.':17 .'- o .~,,,o ,, ~ Ioo .' ..... - . ......: .;.;::.,. .. ~ :..~ .... '~p,~, ."...': ... . . . . . Jl't' :' 4:::: -""" : ' i:.:7': 4:';:": ?; :~.?: ~tl'i~.' ''' ''~ ' .' ' '" oj - o~. '..' tl I '.':. ".:!'!.i" :?)!!ii:?.. ion '~..~ '"'".:;::?:':~'~'-~'~--~':'~::?' :~~. ,,,/e,,^,.~ ' . "' ' °*''? 'f~:~. t'?" ~':; .:,::,'..' '":" ' · 0'~ - oB" 1 o'~.' .'.:'i:'"' .~.~. 8 8.3 o~- os~.2..,~\ I so ')34 ,-....~:. 5^~e. . .- o9- I~ 2.3.21 ~.oo. '. '" li,f ~.~ .,... · m i j ii i i iii i i , ,,1 i i , ii. lmm iii i I I m ANALYST NOTES: DISTRIBUTION DATE REPORTED , DATA REF. CHECKED BY ' CON Fi D E HT!A L ~,~.ow~ Chemical Engineering Group (P. E. Lab) ., .. 'CORE ANALYSIS DATA--"PLUG ANALYSIS" , , couan ....... co~ ~E · . . fiELD OR LOC' CORING FLUID HOW PACKEDz !-1 Sealed ·; C] Uns~led ~.~ III I I I Q III I I i ii i i ii CORE NO. PERMEABILITY COLOR SATURATION ~ ' RECOVERY POROSITY MD. INDEX % PORE SPACE ' ~ItI, ORIDE~ D~SC RI PTIOH DEPTH % Hodz. Vert. NO. O11 Wcfl~ ., i ! ii i i ii i Re ~,1 :5 o i~Z. ~t~ ~o. ~' (eom'o) ' ";":':~"' - ·_,_ :.. -,.-..',,--,:-:"-':..- .1 ss ~ &. :$~,~L&..,t ~' $$o" ' '' : '... '.',..' ...-_ ,, .; "-~.'.. '~ :: /..';. ?.'-:',. :'::'T'.,~'s, ¢'.~- ,~ .L. · Il -I'1 ., ' .' 2.&o'":'. '-"~:'"':,'""';':..,.,.~:... :-: ..... .... ... ,:'">'"'::,,.,...~., · I~ ---~$ Z, lo"!'il ';,?,:":'%'- :-:-'-.;'~',: ~ S'.i':. I1.~ "~'~"'""" ";' fn~m...:",..-"-... ,, "'.'; .'.,::?. - i' :',-. ' 18 :s .. '. [,,~"'"'. . ~,,.I-:iii 65,t, :'~"'~'"*"~'"'~?'~"' ':.'~ .. . ! ,~ - ~ .' f,. ! o · ll,.,~'~'" .t. $ ~.'~ ~ ~,:~;~.r-~',.,,..~: ::..:.' .. Z,,!-~.L i)o.& , .-':.' ' ' '-,"-:..,::...' ''~' '.,',',,?::,,' :'" """" ,......,.:........,;:-.,.:.~,..~... :~.~' - 2.~-z.~'· ','. 15o , '--.. :-';.'..~ ,"'~'~":."-'.,~.,,, ,,,:., [..'t., 68.8 ',?.77~;~.:',~,"~?:% ' , , · 'e.~ ,,;~'e'i ~," ;¢..; ~,', .,,..... ,,., ,.,- ~ ~ ., · , I III I I II I I J I I ANALYST NOTES: DISTRIBUTION DATE REPORTED .. DATA REF. · CHECKED BY CONFIDENTIAL" Co CORE NO. ' , ..~.. - mnos~". , AAD. :. :' ' :'-'% ponn SPACn ',' IIZCOVEEI' . * IHDI~(:- .,**; ii ii · ..................... ~, ~,~;..-:.,-%:,~':;: ~ ~, . .... . ~.-. . .. .., .... . .: ..,.,. . . ....: ,.., . . . , : . .. ~..:.;,;. '?',~ ~ .'~: ? ~:.:'ji.;3~,~'*. 3:$ :::? ~: '.~o:~:~( ! 0."1:'~'~: .'--: .... ,'~" "-: · -, ~ .... = ,~ ,--~ ~,- :,, ........ ,~,,~.- ~-;,~ x .... .-.,,~,) . .~.' - ,,,, '~ , .... ' .~ 'r2 ~,~,.· ",',~ .... ~;* ,', ~, ~.:~ 7~.'i,i,. ,;.%**..., :-..~ · ~:..~ .~: .;.. .,~' '.:.',* ,, ~ ,~ , * ,~le,-$'-- ..~'F,' '~ '"~',',-~ ..;.~.-'.'*,',"***~'~.'-"-~": '-~,':..~=~-",::...:,',~.- ~'' .:.,:,~,. , ",-':- · ,.*~*,:, ..: ~-'?" %~ ~ ,- X";~, .-, .,, , ii:!:-: ;:~ ~1 - '~ 'i:'.':! ~:;:":' ~ 0 ~t ~! i;;;- ~ ,o: '. ~:~ .'"";~.,..:.~.,,.-.:..,...;~'":' "'~'~:.:,.~,':' ..:~.~/;!'"~' '"~?~....:: ~; '.~ ~ ? ii':)'~[ ~'I % '-' : '""~""*"""':, '~.~.'~ ~': :?Ii ?:, !,~.,~ :',,;,.,,4., :~f~,:,?,~4'; -.,?.-~,. ,,,~,~.~,,,c~,~,.r. ~, .~.~.~, ~ ?' !~ .:":i}: ~- ~ ...::. :!~x,e., "'~'"'"'"':"~' "' ~'-." ':'. ~-~ ¥9 ::" ." f.i',.o :'1~-o ', i .... '?':'?' ':'";'"'"~'"??' '~""' ........... " ~'~"';"*'"~ ...... '""~:'~'"' :'"' .. ~* 3 ~ 1,1 · .,,, ..., '~,', .,:,, ,: · ~o '. ~il '' !1~" '--::' [1.t .... ....... ,.,.~.,..? .,,~.,,,,= ~..~, l~.o G2..~ ,~1. ' S'L LO.[ "ISu ., IO.b G~ i ti i i ii i J ii ii i i i · , '; .... . :.,'~, ;,' :, -~, .:.~........~, . ..... .. · ~*. ~ ~ ~i~ ~,4.417¢..~ '~ ., ,'' '* '~ : . ' ' ': ' · .... DISTRIBUTION .,~,.,~"::~:fi,:.~, :~,;~f..:: .... '.:.'...,: ..... ':'. :'. ' ' ANALY~ NOTES: . : .. :.~::~. v ,.,.,.?,* .... :';?.:,' ... . ... ...... . ;~....~:::..,~:::,~,.,;:/,.~..:.,:.::,. ;....:.~: .. .. ::?. .,, ,:.~;'..:.. '".,. .... :' . :.. DATE REPORTED -- . ' ,, · . ... · .., , ....... .: CHECKED BY · ,: ,,, .... , .... ,, '~," ', ':: .......... .," '," .*"'"' "':':' "':". ' ' ~PPROVED ' '-' " ~',','~ ' ,.,;~ , .... , ' ' i'"'.', ,:, "" '", · '. . ~,.,q,',, . ~.', ,~ ~,, -. ',~,,,,~q' ,,,,,,~-'?,, t,~ . .'.* .,,,,~,,, ,'~' ' ~' .' .: 4. ' ,''~ ~' ',), ' IN~t~RPt:IRA[ £D -- 10, 0 Chemical Engineering Group (P. E. Lab) CORE ANALYSIS DATA--"PLUG ANALYSIS" C OPERATO COUNTY CORE TYPE & DIA .... 0 Unsealed FIELD OR LOC CORING FLUID ., . C] i i ii iii i i ii CORE NO. PERMEABIUTY COLOR SATURATION ~ RECOVERY POROSITY MD. INDEX % PORE SPACE CHLORIDES D DEPTH % Horlz. Vert. NO. Oil Water $,5~.- $3 2.:3.3 (,S.( ';.~ 6o..~ 5~ - $~~?.?..S ?.9~ ·~.~ ~8.~ ', r,,~ ~o ~. ~, ~. $~ - ~? ~3o " /o.~ .%4"" 5A~.. ' &l - ~S /~.1 ' 300 .s.z ~.3 8" ' ,, i i i i iii i ii IIII II I III I I II I II I I I , I Il I I I II AN~WST NOTES= DI~B~ON DATE REPORTED , , DATA REF. CHECKED BY CONFIDENTTAL · OPERATOR Chemical Engineering Group (P. E. Lab) CORE ANALYSIS DATA--"PLUG ANALYSIS" COUNTY CO.~ 'rYi'~- & _ i LEASE & WE ~EATF HOW PACKED, C] Sealed '' C) Unsealed HELD OR LOC. ,' ,,, CORING FLUID ...... [1, , ' ,, C i i ~ i~ i i iii iiii iii iiiii ii CORE NO. PERMEABILIT~ COLOR SATUPATION RECOVERY POROSITY MD. INDEX % PORE SPACE DEPTH % Horiz. Vert. NO. Oil Water " · i i ° ii llll I I i , ,. i iiii 'iii i , I i i i i i i i i i i ~ i ,, ~' ~: - ·' .,~?, ~/..~ g13:~- 1~/- $.l.g 16o ::';. "'-.';"::::' """ 'L* '~'~:'~";';'"' ' · .. 'J~. - 3.f · : il.3 ' "l Oo ( .'L 3~..~ :~.,~.-.:,.:,:~..:.:,:...:. ~.^,.~ ',.:.;~: ~...~:;' :. - '~/, - ~'~ \_~.~..3 ./3~-o "?"'~:;'"?~' ' $.g 61.1 ~'~ ' is .. ~.~..~, /,30"'~"'::;::':"'~:~ .,..... loi~. &~.~ .' "j~ - l~ ~'.$/ ~O "":: .. i'~,$. :.,~,~,$':'-?'':-'''-,~:-'-''';-~' 80 ~1 ~1o '?'::::..:.:, s,:?..-.,~,,-.,.,~,;:,~,:.,: , . . · ' - .....,.,..~..,..,. ,.~. .... _~~. . . , .' ..;' :r .. ~,,&.r'- : - ~g ~~ 3 ~'o. ':'~"::""'~:':' ~. 9~o "::-'""-~"':":'~::'~ """ ' ,....,, . ....:~ .... .~.,.~,.. ~~, .. 3~ - ~1 '~t-I 330 3.3 ~1.o . , . ANALY~ NOTES: DI~B~ION ' , DATE REPORTED ......... DATA ~F. "' CON Fl DE NT A L ,.. ..... :.,.,.. ' . . .. :' oeEe,,To~ : COUNTY C FIELD OR LOC ! tN~RPORA,.-D- 18~0 Chemical Engineering Group (P. E. Lab) CORE ANALYSIS DATA--'PLUG ANALYSIS" CORING FLUID, CORE TYPE & DIA · t HOW PACKED, E] Sealed I-1. Unsealed · i i i Ifil I I I I I I CORE NO. PERMEABILITY COLOR SATURATION RECOVERY POROSITY MD. INDEX % PORE SPACE CHLO~DE~ D E S C R I e T I O N , ,, DEPTH % Hm. iz. Vert. NO. O{! Water r, ,u i ~ i i o~.e. :tr..~' "3 ! ~ 3 - e~i't. CuT.. ~S' R,~,.. ;gl93-$~. Z0,.,q' ;,./ l~'.o .... :' " ' k,..o'~o,. · ." ,... ",' i~",¥.,. , ~, · / '. , .... ' ~'. ~;~.o.a ,.. '~,.° "' '~ ..:;!ii.i.;~i~, ,~ ~, ~is.~," · .si, -9'~ [94/. t?.. ":':'?":""';~ - - ... l .~'--1 ........ ...... .i:i:,i:!j::i;.i .;, ~7~., ':'&L.o :,:,.;.,.:s~;i.,:~..,t~.::,.:. F,'ve. e~,. a,~.., -... '-.. · '.. ss - az.o,, . - ~','-.'~ :::: "~ .3::' ,s~ i'" . .' 0L o . '.' :....,.,.~.,,Z~¥ '08 -09 .'-'-:,-" -, ! ,,.~ _ , ._ _ . ./ · · , "' ' ~ ~ ~ mi ~lU ~ ! ~ ~ ~ , ~1 ANALYST NOTES: DI~rRIBUTION . DATE REPORTED , DATA REF. CHECKED BY · AtlanticRichfieldCompany North Ame~'i 'roducing Division Alaska Distric~t Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 August 4, 1969 Mr. Thomas R. Marshall, Jr. State Division of 0il & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 SUBJECT: Samples and Core Chips Atlantic Richfield Co. - Humble 0il & Refining Co. Put River State 7-10-14 Sec. 7-~10N-R14E, UPM Arctic Slope, Alaska Dear Mr. Marshall: On this date, August 4, 1969, I hand delivered to your office, the Alaska Division of 0il & Gas, the following: 1) Seven boxes of dry samples: 2230'-9903'. 2) One bag of core chips, Cores 1-5. Sincerely, Steven C. Vokurka Geologist SCV:cr Receipt Acknowledged: Date: ~roducing Division AtlanticRichfieldCompany North Ame ~.~ Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 August 5, 1969 Mr. Thomas R. Marshall, Jr. State Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 SUBJECT: Atlantic Richfield Co.-Humble Oil & Refining Co. Put River State 7-10-14 Sec. 7-T10N-R14E, UPM Arctic Slope, Alaska Dear Mr. Marshall: Transmitted herewith is the following: 1) Dual Induction-Laterolog, scale 2"=100' 2204 feet to 9903 feet. One blue line print and one reverse sepia. 2) ~Baroid ppm - Sample log, scale 2"=100' 2240 feet to 9903 feet. One blue line print and one reverse sepia. Ail of these logs are marked with ARCO Confidential Number 19-0208-11. Please acknowledge receipt of this data by signing and returning one copy of this letter. Sincerely, Gene ~. Richards GER:cr Receipt Acknowledged: Date: O~L AND GAS CONSERVATION COMMITTEE ',MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL ~ GAS ['~ WELL L_J OTHER N~E OF OPgP,.ATOR ~ ~ 4. LOCATION OF REPORT TOTAL 'DEPTH AT END OF MONTH, CI-IA~NGES IN HOLE SIZE, CASING AND C~-¥IENTING JOBS INCLUDING DEPTH SET AND VOLLrM'ES USED, PERFORATIONS, TESTS ~ RESULTS, FISHING JOBS, JLrNK LN HOLE A/~D SIDE-TR-%CKED HOLE AND ANY OT~IER SIGNIFICANT CI-ZA.NGE,S IN HOL~ CON-DITIONS. ~~'~o ~O'PL--W~T~- 3000 ps'~- I5'm/~.- Dec~, ~o, P~u~ L~ueo ~ 15oo e~,. [o~t ~, ~ ~L~, ~aO, ~aa L~,~oe~ . 0 E~Report on tNis form is required for each calendar month, regardless of the status of operations, anO must be file~ in d~plicate .......... ' .... with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~i,- ~:v. s-a~ OIL AND GAS CONSERVATION COMMILEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL ~. GAS WELL j~ WELL i,__~ OTHER 2. NAME OF OPERATOR CODE - 6. LEASE DESIGNATION AND SEI~IAL NO. j'~L 2t3 7. IF INDIAN, ALxDTTEE O.-R TRIBE 8. U'N'IT FA_~%{ OR LEASE NA_'",IE 3.' ADDRESS OF OPEI~ATOR 4. IX)CATION O'F 1~.. PE~lVIIT '~TO. REPORT TOTAL Dt~PTH AT END OF MONTH, CH.A~TGES IN HOLE SIZE, CASING AIN'D C~WIENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, P~ORATIONS, ~TS ~ ~SULTS. FISHING JO~, J~K ~ HO~ ~D SIDE-~CKED HOLE AD ~Y O~R SIGNIFIC~T ~G~ ~'~e~~'No, I; ~'~ ~ ~ " ,,, , = , ' 14. I hereby ~ify ~t the for~o~gi ~ t~ ~d ~ /C ~,". _ ......... , .. ,. :: ./ / ~' ~, , '-) ..... ~ . ' ,.:, ( ~/ NOTE Report on ~is f~rm is required for each calendar month, r egardl~s of the status of operations, and must ~ filed in duplicate '- ...... with the Division of Mines & Minerals by the 15th of the succeeding menth, unless othe~ise' directed. ~-v.. T E A K · su uc~am ~MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, WELL ~ WELL 2-J OTHER :2. N~E O~ OPERATOR ~ ~. ADDRESS OF OPhiR t er. t.. D Cc,. LOCATION OF WELL 6. LEASE DESiGNAiION AND SEI:{IAL 1510. 7. IF INDIAN, ALOTTEE O.~ TRIBE NADIR 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., Ai.. (BOTTOM HOLE oB,rECeIVE ) 12. PEF, bIIT 1VO. REPORT TOTAL DEPTH AT END OF MON/'H, CEA/~GES IN HOLE SIZE, CASING A/VI) CE3iENTING JOBS INCLUDING DEPTH SET A/ND VOLU1VfES USED, P~OHATIONS, ~TS ~ ~SULTS, FIS~NG JO~, J~K ~ HO~ ~D SIDE-~CKED HOLE ~ ~Y 0~ SIGNIFIC~T ~~ ~ HO~ ~ITIONS. 14. 't hereby ~ify ~t the fo~o~ ~'~d ~ t. ' /~ ': /? " " ,.' : - . I Il I I I I ,ll~ I Ill ~[ , If I~ I .......... / NOTE--Report on this form is required for each calendar month, regardless of the status of operations, anti must be filea in d~icate with the Division of Mines & Minerals by the [Sth of the succeeding menth ,nle~ O[L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. 3. ADDR~S OF OPhiR 4. ~CA~ON OF LEASE DESIGNATION AND S~IAL IF INDIAN, ,.%~T~E OR TRIBE NA~IE 9. WELL NO. / IT,FA~:~M OR LEASE 10. FIF_J.Z) AND POOL, OR WILDCAT 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND C~WIENTING JOBS INCLUDING DEPTH SBT A2XTD VOLU'IVIES USED, PER~"ORATIONS, TESTS ~ ~SULTS. FISHING JOBS, J~K ~ HO~ ~D SIDE-~CKED HOLE AD ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. 1,t. ! hereby 4rtif¥ %ha: thej'~br~go~ is ~e.~d ~e~ s~G~~'~,4~ ..... ~J&.~' . ~ ~,, : - , ....... :; ,, ::,,: .... z ....:', ,,- .I ' ~/ <>' ,, ' / ,,, (" ../ ~0TE~Report on'i~is farm is requke~ for each calendar mont~, regardless of the stat~s ot operations, and must wit~ the Division of Mines & Minerals by t~e 15t~ o~ the succeeding menth, unless ot~e~ise directed. Form No. P--4 ~ i ' R,~,r. -~-~o-6'~ STATE OF ALASKA SUB.~rr ]2q DEPLICATE J OJL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL ,~ GAS WELL WELL ~.._~ 2. NAME OF OPEI:t,A. TOR OTHER 3. AD~ AP1 NUAIERICA.L .~%LOTTEE OR TRIBE NA-~IE 8. L'~,'IT,F.~:~'%{ OR LEASE 9. WELL NO. 4. LOCATION OF WELL 10. FLEI~ %VILDCAT J /.z&,~z; c,~7-- ~ 11. P~IT NO. 13. REPORT TOTAL D~ AT ~D OF MON~, C~NGES IN HOLE SI~E, CASING C~TING JOBS INCLUDING SET ~ VOL~S USED, P~ORATIONS, ~TS ~ ~SULTS, FISHING JOBS. J~K ~ HO~ ~D SIDE-~CKED HOLE A~ ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CO~ITIONS. TRM OKG ,~/ KLV ................. REL ,mm,,,,...,.-. FILE ines & Minerals by the 15th of the succeeding month, unless otherwise directe;~erati°ns' ancl must be file~J in duplicate Operator Lease & Well Atlantic Richfield Co. Put River State No. 1 (7-10_-14)_ Spud Date T~e following information is in the bank file: i. P-3 D~'~e' in Bank File ~KeDort Date i~.::r':: :):ia ~TPate in Bank Fi~ it. ~~ ........ (5: '~ 2 P-7 - Comp let io:: 3. Well History ............................................................ Directional Survey .............................................................. 5. Electric Log ; ............................. Blue line ,~,: - 6 Lithology or Mud L,~' Blue line l 7. Other Log 8. Field Trip Corm No, P--4 REV. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL/.~ WELL NAA'IE OF OPE!q~TOR OTHER 3. ADDRE-qS OF OP~ATOR 4. LOCATION O'F WI~.~,1- ,- LEASE DESIGNATION AND $E'~IA~I~)' ..---.~__ 8. tLIX'IT,F.~t~'~ OR I.,F, ASE NAAIE / 10. FIEI.,D AMD POOL. OR WILDCAT _ /-/./,,.,(s ¢,~ 11. SEC., T., R., A'I., ~BOTTO.M HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MOINwPi, CI4-A2CGES IN HOLE SIZE, CASING A2XTD C~WIENTING JOBS INCLUDING DEPTH SET AND VOLLTMES USED, PEP&ORATIONS, TESTS AND RESULTS, FISHING JOBS, JI_TNK IN HOLE A2~D SIDE-TRACKED HOLE AND A_NY OTI-I]gl~ SIGNIFICANT CI-ZA~E8 IN HOI_~ CONI)ITIONS. 1'4. I hereby certify th~t~he for~goLng is tru~ and correct NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding menth, unless otherwise directed. Form No. P--4 lq.EV. 9-30-6'; WELL ~ WELL~ OTHER 2, NA.ME OF OPEP~ATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WTM HLB --_ TRM -_ OKG KLV ~. AP1 NLq.'iERICAL CODE HW'.< 6. L~..&SE DESiGNAiION AND S~EiKI__AL ~-O_..~ III ,4~-..~ F$,$ FILE 10. ~U~:TJ~ A_ND POOL. OR WILDCAT ll. SEC., T., R., M.. (BOI'TOM HOLE OBJECTIVE ) 19. PEPdViIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CH. ANGES IN HOLE SI:~E, CASING A_N-D CE1ViENTING JOBS INCLUDING DEPTH SET AND VOLU/Vi~S USED, PER~ORATIONS, TESTS A/XrD I:LESULTS. FISHING JOBS. JI/NK IN HOLE A3qD SIDE-TRACKED HOLE AN'D ANY OTHER SIGNIFICANT CHANG~ IN HOI~ CONDITIONS. DIVISION OF OI/AND SAS ANCHQib~.O~ 14. I hereby certify thJat th~ foregoing ~ true and correct 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 Division of Mines & Minerals by the 15th of the succeeding menth, unless otherwise directed. AtlanticRichfieldCompany North Ame , Producing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 RECEIVED M~v 1 ~ DIVISION OF OIL AND GAS ANCilO~AGE CONFIDENTIAL May 12, 1969 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska Attention: Mr. T. R. Marshall, Jr. Gentlemen: Reference: P:ut. River State ~1 (7-10-14) Section 7, T10N, .R149 Permit ~69- 36 This is to advise that the above referenced well was spud May 12, 1969. Very truly yours, Senior Drilling Engineer JDK:tll DIVISION OF OIL A~ID GAS Apr11 22, 1969 Put i~1ver Stabe (7-10-14) No. 1 Atlanttc R~chf~eld Company, Operator Eacloseei is a copy of ~. Alaska ~partment ef Ft~ ar~t Game s'~pulattons for the ~ve refe~.~ ~etl. These stt~la:Io~ ceest~tute a ~t~ ef the permt:t ta dr~11 the .~eI'1. Enclosu:~ FORM FG- 74 J , '~REV. 2- 67) .~,, ¢, MEMORANDUM TO: I-- Homer L. Burrell, Director ~')Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 FROM: Robert J. Wienhold Habitat Biologist Alaska Department of Fish and Game 1018 International Airport Road Anchorage, Alaska 99502 State of Alaska FILE NO: DATE : April 18, 1969 TRM OKG KLV HWK REL FILE SUBJECT: Put River State (7-10-14) No. 1 Atlantic Richfield Company, Operator - In reference to the subject well, the Alaska Department of Fish and Game requests the following Wildlife stipulations be attached to the permit to · drill: 1. Prior.to the beginning of drilling, a sump of sufficient size to contain all waste fluids will be constructed. The sump must be lined with material impervious to oil at all seasons during the year. 2. Prior to the beginning of drilling, adequate ditching shall surround the area, taking advantage of the natural topography of the land to insure that any spill that might occur Will be drained into the sump. · . 3. Prior to abandonment of the site, the sump must be cleared of all oil and covered. 4. The operator must dispose of all refuse, waste, debris, garbage, pallet board, visqueen, barrels, etc., by being burned and non-combustible material must be disposed of by removal to a site acceptabl'e to the Alaska Department of Fish and Game. 5. No stream or body of water will have any foreign material added to it. This includes vegetation, soil, petroleUm products, or refuse. 6. All preparatory work for drilling will be done prior to May 1, 1969. This includes construction of access roads, airstrips, gravel dumps, and necessary excavation. cc: B. Hilliker APR DI¥1$1ON OF OIL AND GAS ANCHORAGE (~s DIVISI~ OF OIL Am GAS April 17. 1969 Re: Put River State (7-10-14) No. Atlantic Richfield Company opera ~ Oear Sir: far ~,t't to' Welt samp)es, a~:, ,core chips ar~ required, Please.here ~e eth~ that c~t .o~ 9 5/8-t.~h cas'.i~' $halt be. s~lctent to cover a11, po~t(.ally proactive zones and' .pre~nttan :~i;pment shall 'be Series 1500 ,ar better. Alaska ,~rt~ent of Fish an~ ~e st~tpulatt~a.,s, ~hen received, will be ~,t~,~t~ ,el' subject-per, it. ~n the eveut af a~o~nt, please notify ~is office adequately in advance so that ,~e~y ~bave a wlt~s presen~t.. Very truly y~rs, HLB Enclosure ~e,r L, 'Burrel] FORM SA- I B . MEMORANDUM TO: l-- D,ile i~11tmjtm~ De~ CemfSStmmr FROM: ~ L. Butte11 State of Alaska DEPARlJlEKr OF IU~T~ ~ES DIVI$1~ OF OIL ~ GAS DATE : ,4J, p~t 17, 1969 SUBJECT: Put. River State (7-10-.14) I, Io. 1 Atlant. tc Rtcbfleld ~, operator En~l~ arm ~ approved ap~lftitton for permit to ~11. a locatto~ plat, and a chJ~ tn the amount of $~ for ftltng fee. FORM SA- B MEMORANDUM TO: I'- ~#.~ FROM: Biwr L. l~rr~11 Dtreetor State of Alaska DIVISIO# OF OIL AI~ gAS DATE SUBJECT: Put River State (7-IO-14) Bo. I Atlantic Rtehfteld ~, operator ~1~ ts a ~ of ~ appro~ application to d,-,lll for~ ~ ~ ~11. FORM SA- I B . . MEMORANDUM TO: F- Leader e~ Lead $~udies FROM: tklmr L. hrre11 Otmct, m, State of Alaska 0EP~ OF I~ATUI~L RESOtJRCES DIVISION OF OIL DATE : .J~pl~l 17, lng SUBJECT: Put River State (7-10-14) He. 1 Athmflc Rtc~fleld ~, operator ~hsJl 'ts u i~pltutt~ fa" :~t to d~ll ~ & Ioctflo~ plat ferthe ~t~tl~ ~ w:11. Pl~e ~t~ tf ~ ~ a~ Fish ~ :Ric~fieldCo~npany North Ame~~ Producing Division Alaska Dist% Post Office ~.. 360 Anchorage, Alaska 99501 Telephone 907 279 1411 O0 FIDENT AL April 11, 1969 State Divisions of Mines and Minerals Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska Attention: Mr. T. R. Marshall, Jr. Gentlemen: Reference: Put River State ~1 (7-10-14) Enclosed please find Application for Permit to Drill, the location plat and the $50 filing fee for the above referenced well. Very truly~urs, ~ ~n~rK;~~ng Engineer JDK:tll encs RECEiVEE) APR 16 I969 DIVISION OF OIL AND GAS ANCHORAGE OIL AND ~"~AAS CONSERVATION CO~ITTEE' TE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK ~. ~¥I'~ OF WORK DRILL [] DEEPEN [] PLUG BACK 1-] b. TYP~OF WgLL OIL ~ OAS ~ 8,N~L~ ~ ~UI.TIPI.~~ WILL W~L~ OTHER ZON~ ZONE 2. NAME OF OPE1ZATOR Atlantic Richfield Company 3. ADDRESS O~ OPERATOR P. O. Box 360, Anchorage, Alaska 99501 2343'S & 2436' W of NE Corner, T10N, R14E, UM i ~ . , ,., ~;~ Same Sec. , 4. LOCATION OF WELL ,~t surface At proposed prod. zone API 50-029-20017 6. LF_,A~E DESIGNATION AND SE3q. LAL NO. ADL 28313 /o-/- 7 5~ 7. IF INDIAN, ALLO~FEE OR TP./BE NAME '8. UNIT, FAR~! OR LEA.SE NA/%IE Put River State 9. VvrlZLI, NO. #1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOI~I HOLE OBJECTIVE) Sec. 7, T10N, R14E, 13. DISTANCE IN MILES MD DIRECTION F:~OM NEAREST TOWN OR POST OFFICE* 12. · '~ ' ,. . 380 North from Fairbanks, ...Alaska 14. BOND INFORMATION: ',) ~Statewid~.~ ~o~ ~0. Federal Insurance Co., ,, ~011-34-40 .~o~ $100,000 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE. FT. (Also to nearest drig, unit, if any) 2844 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING,. COMPLETED, OR APPLIED FOR, FT. -N/A 21. ELEVATIONS (Show whether DF, RT. CR, etc.) 25' GL (Estimated) 16. NO. OF ACRES IN LEASE : 2560 ' ' ~ ~ 19. PROPOSED D~ ': "10,000" 17. NO. ACRES ASSIGNED TO THiS WELL 64O 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* 4-25-69 (7-10- 14) 23. PROPOSED CASING M-ND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRA~)E t SETTING DEPTH qUANTIT~ OF .39" 30" 157, 5~ B 60 ' ' circulate __ 26" 20" ' 949 'H. 500' .t.o 10)0' . . circulate 17-1/2" 13-3/8'" '54.5 & 61# J 2000' circulate . 12-1/4" 9-5/8" 40 & 43.5~ S,95 10'.000" ~ ' "1000 sacks · ........ ,.,,. Drill Log, Core, a 'Test at selected intervals to Penn-Mississipian (Lisburne) ~ approximately 10,000'. 20" Hydril installed & tested on 30" & 20" ca~ing %o 200'0'. 13-3/8" Hydril & doUble BOPE installed & Tested on 13-3/8" & 9- 5/8" +'~ TD. RECEIVEI) APR 1 6 1969 IN ABOVE SPACE DESCRIBE PROPOSED PROORAM: If proposal 15 to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directlonally, give pertinent, data on subsurface locations andl]~l~q~lcOl[ AND GAS true vertical depths. Give blowout preventer program. ~l~i-t~(~!= f , 2 I here certify that the oreg ' g True and' Correct cefor State office use) coNDITIONS OF .~PPROV.a~, IF ANY: ISAMPLES AND CORE CHIPS REQUIRED ,, ~ YES ~ NO [ DII:~ECTIONAL SURVEY l~X~UIl%ED · YES ~8~ NO APPROVAL DATE Apri 1 17, 1.969 APPROVED ~Y.- _. ~ . ~'/~- ~~ TI~ Director· *See Instructions On Reverse Side DATE Apri 1 17, 1969 ._ L_ 34 I0 15 22 35 I 36 I I 31 11'6 I I I ' I T- -I- --I T- I I I I I I ' I 14 I I I I I I I I I I I I 23 I a4 ~e I zo I I I I I I I I I / I L 't J---- SCALE: I"= IMILE CERTIFICATE OF SURVEYOR 21 I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made byme or under my supervision, and that all dimensions and other details are correct. Date SURVEYOR I PUT RIVER STATE NO 1 Located in Surveyed for ATLANTIC- RICHFIELD Surveyed by F. M. LINDSEY 8~ ASSOC. LAND & HYDROGRAPHIC SURvEYoRs 2502 West Northern Lights Boulevard 13ox 4-081 Anchorage Alaska