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Alaska Oil and Gas Conservation Commission
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ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL
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SCAN.LO BY: ~;~ BRE. V,NOENT S.ERYL MA. IA
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RESCANNED BY'. BEVERLY BREN VINCEN~ARIA
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PLUGGIN,.~ & LOCATION CLEAA~CE R~PORT
State of Alaska
.ALASKA 0IL & GAS CONSERVATION COMMISSION
· .
Review the well file, and-e_enm~e~t on plugging, well head
Marke_ '.nos= or plate:
Location Clearance:
Code
Data
· o
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
March 30, 1998
Mr. David J. Johnston
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: 3Q-08 (Permit No. 86-193,397-173) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the recent abandonment of KRU 3Q-08. This well was
sidetracked and re-drilled to an alternate bottom hole location and renamed 3Q-08A.
If there are any questions, please call 263-4622.
Sincerely,
W. S. Isaacson
Drilling Engineer
Kuparuk Drill Site Development
WSI/skad
ORIGINAL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
I Status of Well Classification of Service Well
OIL [] GAS [~ SUSPENDED r-"] ABANDONEI~ SERVICE ~
2 Name of Operator 7 Permit Number
ARCO Alaska, Inc 86-193 & 397-173
3 Address 8 APl Number
P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21681
4 Location of well at surface ~ ~ , 9 Unit or Lease Name
~ Kuparuk River Unit
2241' FNL, 2207' FEL, Sec. 17, T13N, R9E, UM [ 10 Well Number
At Top Producing Interval
1128' FSL, 1608' FEL, Sec. 7, T13N, R9E, UM [ 3Q-08
At Total Depth 11 Field and Pool
1189' FSL, 1823' FEL, Sec. 7, T13N, RgE, UM KUPARUK RIVER
5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. Kuparuk River Oil Pool
RKB 60', Pad 22' ADL 355024 ALK 3574
12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions
02-Jan-87 17-Jan-87 04-Oct-97 P&AI NA feet MSL 1
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost
9400' MD & 6579' TVD 9281' MD & 6493' TVD YES U NO XL~ NA feet MD 1600' APPROX
22 Type Electric or Other Logs Run
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD
16" 62.5# H-40 SURF. 115' 24" 1875# Poleset
9.625" 36.0# J-55 SURF. 4935' 12.25" 1200 sx AS IV & 325 sx Class G
7" 26.0# J-55 SURF. 9361' 8.5" 630 sx Class G & 175 sx AS I
retainer set @ 8977' MD, bridge plug @
7896' WLM, balanced plucj @ 8882t
24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
all perfs abandoned
26 ACID, FRACTURE, CEMENT SQUEEZE, ETC
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
lay balanced 15.8#, Class G cement plug from
8529'-8882' MD
27 PRODUCTION TEST
Date First Production Method of Operation (FIowing,N/Agas lift, etc.)
Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO
TEST PERIOI:
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE:
28 CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
N/A
(.,a.., Cons.
Form 10-407 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 9074' 6343'
Bottom Kuparuk C 9088' 6353'
Top Kuparuk A 9088' 6353'
Bottom Kuparuk A 9160' 6405'
31. LIST OF ATTACHMENTS
SummaB/of Daily Drilling Reports
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Prepared by Name/Number Sharon AIIsup-Drake/263-4612
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and Icg on
all types of lands and leases in Alaska.
Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
Date: 3/26/98
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
WELL:3Q-08 RIG:NORDIC
WELL_ID: 998767 TYPE:
AFC: 998767 AFC EST/UL:$ 855M/ 995M
STATE:ALASKA
AREA/CNTY: NORTH SLOPE EAST
FIELD: KUPARUK RIVER UNIT BLOCK:
SPUD:10/16/97 START COMP:01/23/98 FINAL:
WI: 0% SECURITY:0
API NUMBER: 50-029-21681-00
10/13/97 (D1)
TD: 0'( 0)
SUPV:DLW
DAILY:$
10/14/97 (D2)
TD: 0'( 0)
SUPV:DLW
DAILY:$
10/15/97 (D3)
TD: 0'( 0)
SUPV:RLM
DAILY:$
MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
KILL WELL
Move rig from 3I to 3Q. Prep well site and spot rig over
well. Accept rig @ 22:00 hrs.
23,628 CUM:$ 23,628 ETD:$ 0 EFC:$ 878,628
MW: 9.6 VISC: 52 PV/YP: 11/23 APIWL: 10.0
LAY DOWN TUBING AND JEWELRY
Pumped fresh water and mud to kill well. ND tree, NU BOP,
test to 300/3500 psi. Pull tubing hanger to floor. Lay
balanced plug with OET at 8882' Calculated top of cement
at 8529'
68,479 CUM:$ 92,107 ETD:$ 0 EFC:$ 947,107
MW: 9.6 VISC: 96 PV/YP: 12/47 APIWL: 9.0
PICK UP DP AND RIH W/WS
POOH laying down 2-7/8" tubing and jewelry. Made gauge
ring and junk basket run to 8038'. Run Baker N-1 BP on WL
set with top at 7896'
47,928 CUM:$ 140,035 ETD:$ 0 EFC:$ 995,035
ARCO Alaska, Inc.
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1(3Q-08(W4-6))
WELL
3Q-08
DATE
10/04/97
JOB SCOPE
RIG SIDETRACK, SIDETRACK SUPT
DAY OPERATION COMPLETE I SUCCESSFUL I KEY PERSON
1 YES NO DS-WOLD
'nitialTbgPress IFinalTbgPress ilnitiallnnerAnn IFinallnnerAnn1400PSI 0PSI 650 PSI 700 PSI
DAILY SUMMARY
JOB NUMBER
1003971852.5
DAILY WORK UNIT NUMBER
P&A FOR NORDIC SIDETRACK UNIT #3
SUPERVISOR
REYNOLDS
Initial OuterAnn I Final Outer Ann
0 PSII 0 PSI
SET CMT RETAINER @ 8,977' RKB. SHEARED OUT BALL SEAT WHICH LANDED IN 1.81" ID XO. UNABLE TO REMOVE BALL
OR BALL SEAT. UNABLE TO PUMP CMT JOB. RELEASE FROM CMT RETAINER AND POOH. FREEZE PROTECT F/2,500'.
NORDIC WILL P&A UPON THEIR ARRIVAL.
TIME LOG ENTRY
07:00 MIRU DOWELL CTU. PT CONTRACTOR AND SURFACE EQUIPMENT T/4,000 PSI.
07:30 BULLHEAD IN 90 BBLS SLICK SW.
08:30 RU BAKER OIL TOOLS, PT TOOLS & WELL.
09:00 RIH W/2.13" COIL CONNECTOR, HYD DISCONNECT, TBG NIPPLE LOCATOR, SPOTTING VALVE, CMT
RETAINER.
10:18 VVT CHECK 17.7K UP WIEGHT. TAGGED XO W/1.81" ID @ 8,970' CTM (CORRECTED TO 8,994' RKB). ADJUST
DEPTH TO 8,990' RKB (4' FROM TOOL TAIL TO CENTER OF RETAINER ELEMENT). PUH T/8977' RKB & DROP
BALL.
11:20 BALL SEATED, SLACKED OFF 2,000 LBS. WAIT 15 MINUTES FOR CMT RETAINER TO SET. PRESSURE UP TO
1800 PSI, SHEAR OUT BALL SEAT. NO REDUCTION IN TBG PRESSURE. DETERMINED THAT BALL SEAT IS
SET IN 1.81" XO. SEAT OD IS 1.8".
13:30 UNSTING FROM CMT RETAINER & POOH. FREEZE PROTECT FROM 2,500'.
14:30 TAG SURFACE. PERFORM BOP TEST. RDMO. WELL LEFT WI0 PSI ON WELLHEAD. NO CEMENT WAS
PUMPED ON THIS JOB. WELL WILL BE LEFT SI FOR SLICKLINE TO RERMOVE BTM DV. NORDIC WILL P&A
WELL WHEN THEY MOVE ON TO LOCATION.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Name of Operator
Abandon X Suspend Operation Shutdown Re-enter suspended well
Alter casing _ Repair well Plugging X Time extension Stimulate
Change approved program _ Pull tubing _ Variance _ Perforate _ Other
ARCO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
ORIGINAL
4. Location of well at surface
2241' FNL, 2207' FEL, Sec. 17, T13N, R9E, UM
At top of productive interval
1128' FSL, 1608' FEL, Sec. 7, T13N, R9E, UM
At effective depth
1167' FSL, 1745' FEL, Sec. 7, T13N, RgE, UM
At total depth
1189' FSL, 1823' FEL, Sec. 7, T13N, R9E, UM
12. Present well condition summary
Total Depth: measured
(approx) true vertical 6579
Plugback for
X Redrill
9400 feet
feet
6. Datum elevation (DF or KB)
60' RKB, pad 22'
7. Unit or Property name
Kuparuk River Unit
8. Well number
3Q-08
9. Permit number
86-1 93
10. APl number
50-029-21681.
11. Field/Pool
Kuparuk River
feet
Plugs (measured) None
Effective depth: measured 9281 feet
(approx) true vertical 6493 feet
Junk (measured)
Casing Len g t h Size
Structural
Conductor 80' 1 6"
Surface 4898' 9.625'
Intermediate
Production 9326' 7 '
Liner
Cemented
1875# Poleset
1200 sx AS IV
& 325 sx Class G
630 sx Class G &
175 sx AS I
Measured depth True verticaldepth
115' 115'
4935' 3726'
9361' 6551'
Perforation depth:
measured
9084'-9116'
RECEIVED
true vertical
6349'-6373'
Tubing (size, grade, and measured depth)
2-7/8", L-80, tbg w/tail @ 9005'
Packers and SSSV (type and measured depth)
HRP-1-SP pkr @ 8941', & TRDP-1A-SSA SSSV @ 1812'
i, ..... U :Fi 1997
Alaska Oil & Gas Coils.
cb mgeJ
13. Attachments Description summary of proposal X
__Contact William Isaacson at 263-4622 with any c~uestions.
14. Estimated date for commencing operation
October 4, 1997
16. If proposal was verbally approved
Name of approver ~d(~ ,..~¢::~nI, JS"~o~d Date approvea
Detailed operation program
15. Status of well classification as:
Oil Gas
Service
BOP sketch
Suspended _
17. I h~reby certify that the foregoing is true and correct to the best of my knowledge.
Sigr~i (..Z~'~ i C~t~O~,.~L ~-/ {'~-~lc,z ~' ~tle Drillin~l Superintendant
' co ,ss,o.
Date
Conditions of approval: Notify Commission so representative may witness IAppro_val...N_o.
Plug integrity ~ BOP Test~"~ Location clearance__ I...~.~'"-/'-' /~
Mechanical Integrity Test~ Subsequent form require 10-__~
ORIGINAL SIGNED BY ~oQ~ ~
v r t o m C~ mmlssloner Date ~/ ~ ~'
Form 10-403 Rev 06/15/88 ,~9 '., ~/.~,' SUBMIT IN TRIPLICATE
KRU 3Q-08 SUNDRY OBJECTIVE
to
P & A WELL FOR SIDETRACK OPERATIONS
(reference attached plugback schematic)
PRE-RIG WORK;
o
RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 2-7/8" tubing tail
immediately below production packer. Mix cement. Circulate the cement down coil to
immediately above circulating valve on top of retainer. Close circulation valve and down-
squeeze cement below retainer into A Sand perfs. Use sufficient volume to fill tubing down
through tubing tail and 7" casing from top of fill to tubing tail, plus excess to squeeze away
into perfs if possible. Unsfing from retainer and circulate well clean on top of inflatable
retainer. RDMO CTU.
2. RU slickline unit. RIH and pull dummy valve from bottom GLM at 8873' MD RKB, leaving
an open pocket.
WORKOVER RIG WORK:
1. MIRU Nordic Rig 2. Lay hard-line to tree.
2. Verify well is dead. Load pits w/water. Circulate well to water.
3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation
from perforations. Set BPV.
ND tree. NU and test B OPE.
Screw in landing joint. Pull tubing hanger to rig floor. CBU to ensure well is dead. POOH
laying down all 2-7/8" tubing.
RU E-line unit. Run gauge ring through bridge plug setting depth. RIH and set permanent
bridge plug at 7896' MD-RKB.
Whipstock will be set immediately above bridge plug to allow milling of 7" casing and
kicking-off for sidetrack.
.
,
,
WSI 10/2/97
Milling Fluid
3Q-08 Proposed
9-5/8" 36#, J-55 set @ 4935' MD
back
APl Cf: 50-029-21681
RKB = 6O'
Pad Level = 22'
Abandoned
A Sand Pods
Fresh water
7" Baker 'Window Master - Bottom Trip Whipstock System' set on top of bridge plug,
7" Baker'N*l' Bridge Plug @ 7896' MD.
2-7/8" x 7" Camco ~HRP-1 -SP! Retrievable production packer w/SBR 'slick stick' @ 8931' MD.
Tubing tail below packer includes: 2-7/8" x 1 O' pup, Landing nipple, 1 full jt 2-7/8" tbg,
" ' ' 8" 8' pup (tubing tail at 9005' MD.)
crossover to 2-3/8, landing topple, and 2-3/ x
nf atab e cement reta nor set n tub ng ta'l at +A8977 MD with cement squeezed below, down
to top of fill.
oration @ 9084! MD
@ 9116* MD
of fill at +/~9112' MD.
7", 26#, J-55 pBTD
=9281t
MD
' D
'rD = 9400 M
WSl 10/02/97
" STATE OFALASKA
AL,~,~.,~ OIL AND GAS CONSERVATION COMME.,_..)N
REPORT OF SUNDRY WELL OPERATIONS
O It l G I
1. Operations Performed: Operation Shutdown ,,.
Pull tubing Alter casing
Stimulate ~ Plugging
Repair well
2. Name of Operator
ARGO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK
99510
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
4. Location of well at surface
2241' FNL, 2207' FEL, SEC.17, T13N, R9E, UM
At top of productive interval
1128' FSL, 1608' FEL, SEC.7, T13N, R9E, UM
At effective depth
1167' FSL, 1745' FEL, SEC.7, T13N, R9E, UM
At total depth
1189' FSL, 1823' FEL, SEC.7, T13N, R9E, UM
12. Present well condition summary
Total Depth: measured 9 4 0 0' feet
true vertical 6 5 7 9' feet
Plugs (measured)
Perforate
Other
6. Datum elevation (DF or KB)
RKB 60'
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
3Q-08
9. Permit number/approval number
86-193 / 92-254
10. APl number
50-029-21681~00
11. Field/Pool Kul~aruk River Field
Kuparuk River Oil Pool
Effective depth: measured
true vertical
9281 ' feet Junk (measured)
6494' feet
13.
Casing Length
Structural
Conductor 80'
Surface 4 8 9 8'
Intermediate
Production 9 3 2 6'
Liner
Perforation depth: measured
9084'-91 16'
true vertical
6349'-6373'
Size Cemented
1 6" 1875~ POLESET
9- 5/8" 1200 SX AS IV &
325 SX CLASS G
7" 630 SX CLASS G &
175 SX AS I
Tubing (size, grade, and measured depth)
2-7/8" L-80 ABM @ 9005'
Measured depth True vertical depth
115' 115'
4935' 3727'
9361 ' 6551 '
Packers and SSSV (type and measured depth)
CAMCO HRP-1-SP @ 8941', CAMCO TRDP-1A-SSA @ 1812'
Stimulation or cement squeeze summary
CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL
Intervals treated (measured)
Treatment description including volumes used and final pressure
14.
Representative Daily Average Prqdwtion or In!ection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
Subsequent to operation
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations X
164 136 13
0 0 2421
1100
16. Status of well classification as:
Water Injector
Oil Gas Suspended
Service
204
2542
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
S, ne C.eo.
Form 10-404 Rev 09/12/90
Title Petroleum Engineer
SUBMIT IN DUPLICATE
MORNINg WELL REPORT INPUT FOR PRODUCTION DATE 02/17/93 PAgE 2
INdECTiON WELL STATUS *~*~**~e~***~ **~ S/I? **~
S
T
4 A
E T
_ U
- S
I A1 C C IV IV
ANP CNP D C S AP AP MR NO NOM
Z LJR TJR TE HB EISR ISR'ED JLB JLM T C
0 LEEP UEEP Eg OE VNIE TNIE TI EUB EUS I 0
N OCSS ACSS M KA ECNS ECNS EN CML CMC M D
E WTSI LTSI PF EN NHgS NHgS Rg TES TEF E E
1SWI A 2800 24.87 57 60 900 175 0 5209 0.000
2 SWI A 2800 2656 56 104 575 240 0 1821 0.000
5 SWI A 2800 2635 57 104 500 100 0 1791 0.000
~ SWI A ~uoo'k~/~ ~ iu4 o~o 'asO 0 12632 0.000
12 SWI A 2800 2673 56 104 610 24.0 0 2961 0.000
13 SWi A 2800 2670 57 104 300 80 0 3589 0.000
15 S/I A 2800 1802 54. 104 800 540 0 74.5 0.000
·
16 SW! A 2800 2663 56 104 430 50' 0 2266 0.000
0 ~ ~ 0 0 0 0 0 0 0 .... 0 0.000
0 ~** * 0 0 0 0 0 0 0 0 0.000
TOTALS'
(SWI' 19645 + PWI'
O) = 1964,'5 0.0000
1330 55
***~****~****** HEADERS ***~*****~**** * DRAIN *
PROD ' H20 INd gAS INJ gAS LIFT 1-8 9-16
** METHANOL TANK **
D P D P D P D P P P
E S E S E S E S S S F I
~F I gF I gF I gF I I I T N
90 140 58 2650' 0 0 106 1440 320 1900
· LEVEL TEMP
10 4. O0
F
PU D
CL E
TL gF
0 45
COMMENTS'
38-15 S/I FOR 36 HOUR S. P. F. 0 STARTED AT 10' 30 2/17/93
F U N C 'T I 0 N K E Y S HELP PRINT
DISPLAY FWD/BACK' PAgE 1 PAgE FWD/BACK' OT~4ER INJECTION WELLS (IF ANY)
SHIFTS' 1) RETOTAL 2) UPDATE 3) PRINT D/S 4) REDO S/I, ETC. 5) NEW DS (DS~ TOP)
6) PR'INT S/S 7) S/S MULTIPRINT (CPF~ TOP) 8) D/S MULTIPRIN'F 9) WAG I OR II ~AS
.... STATE OF ALASKA
AI_A~. ,~ OIL AND GAS CONSERVATION COMMIb,.,,ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon Suspend
Alter casing _ Repair well
Change approved program X
Operation Shutdown _ Re-enter suspended well_
Plugging _ Time extension Stimulate
Pull tubing _ Variance _ Perforate _ Other
2. Name of Operator
ARCO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK
99510
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
4. Location of well at surface
2241' FNL, 2207' FEL, Sec. 17, T13N, R9E, UM
At top of productive interval
6. Datum elevation (DF or KB)
RKB 6.0
7. Unit or Property name
Kuparuk River Unit
8. Well number
3Q-08
9. Permit number
1128' FSL, 1608' FEL, Sec. 7, T13N, R9E, UM
At effective depth
1167' FSL, 1745' FEL, Sec. 7, T13N, R9E, UM
At total depth
1189' FSL, 1823' FEL, Sec. 7, T13N, R9E, UM
12.
Present well condition summary
Total Depth: measured 9 4 0 0 feet
true vertical 6579 feet
Plugs (measured)
None
86-1~)3
10. APl number
5o-029-21 681
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Effective depth: measured 9 2 81 feet
true vertical 6 4 9 4 feet
Casing Length Size
Structural
Conductor 8 0' 1 6"
Surface 4 8 9 8 9 5/8"
Intermediate
Production
Liner
Perforation depth:
9326 7"
measured
9084'-91 1 6'
Junk (measured)
None
Cemented Measured depth True vertical depth
1875# POLESET 115' 115'
1200 SX AS IV & 4935' 3727'
325 SX CLASS G
630 SX CLASS G & 9 3 61 ' 6 5 51 '
175 SX AS 1
true vertical
6349'-6373'
Tubing (size, grade, and measured depth)
2 7/8" L-80 ABM set at 9005'
Packers and SSSV (type and measured depth)
Camco HRP-1-SP@ 8941', Camco TRDP-1A-SSA @ 1812'
RECEIVED
OCT 2 1992
&las~.0Jt .& Gas Cons.
BOP sketch
Suspended _
Water Injector
t3. Attachments Description summary of proposal X_ Detailed operation program __
Convert well from oil producer to water injector. (Wellbore schematic attached).
14. Estimated date for commencing operation 15. Status of well classification as:
October, 1992 Oil Gas _
16. If proposal was verbally approved
Name of approver Date approved Service
17. I hereby certify that the fo. regoing is true and correct to the best of my knowledge.
Signed C.J,J. ~ Title Petroleum Encjineer
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity_ BO~Test _ Location clearance__
Mechanical Integrity Test _/'"' Subsequent form require
Approved by order of the Commission
Form 10-403 Rev 09/12/90
ORIGINAL SIGNED BY
RUSSELL A. DOUGLASS
IApproval No.
"
Commisslbner Date
SUBMIT IN TRIPLICATE
Well 3Q-08
Conversion to Water Injection
ARCO Alaska requests approval to convert Well 3Q-08 from an oil producer
to a water injector. This well will be operated as a Class II UIC well in
compliance with Area Injection Order No. 2. Water will be injected for the
purpose of enhanced recovery into the Kuparuk interval between the depths
of 9050' and 9150'. This interval correlates with the strata found in
ARCO's West Sak River State Well No. 1 between the depths of 6474' and
6880' as authorized in Rule 1 of this injection order. A Mechanical
Integrity Test will 'be performed before injection is initiated and every
four years thereafter, in compliance with Rule 6 of this order. This well's
injection volumes, average injection pressure, and average annulus
pressure will be reported to the AOGCC monthly.
RECEIVED
OCT 1992
Alaska Oil & Gas Cons.
Ntchorage
KUPARUK WELL 3Q-08
APl #: 500292168100
SPUD DATE: 02/04/87
ADL LEASE: 355024 PERMIT #:
COMPLETION DATE: 03/01/87 WORKOVER DATE:
86-193
ORIGINAL RKB:
SURFACE LOCATION: 2241'FNL,2207'FEL,SEC17,T13N,R9E
TOP OF KUPARUK: 1128'FSL,1608'FEL, SEC7,T13N,R9E
TD LOCATION: 1189'FSL,1823'FEL, SEC7,T13N,R9E
All depths are MD-RKB to top of equipment unless otherwise noted
60 TUBING SPOOL: 34 PAD ELEVATION:
WELLTYPE: PRODUCER
23
CASING and TUBING DETAILS
SIZE WEIGHT GRADE DEPTH
16" 62.5# H-40 115
9.625" 36# J-55 4935
7" 26# J-55 9367
2.875" 6.5# L-80 ABM 9005
LINER DETAILS
SIZE WEIGHT GRADE TOP BTM
TUBING JEWELRY
ITEM TYPE ID DEPTH
SSSV CAMCO TRDP-1A-SSA 2.31" 1812
SBR CAMCO OEJ 8914
PKR CAMCO HRP-1-SP 8941
NOGO CAMCO 'D' NIPPLE 2.25" 8959
NOGO CAMCO 'D' NIPPLE 1.81" 8994
SHROUT CAMCO PE-500 9004
MISC. DATA
DESCRIPTION
KICK OFF POINT:
MAX HOLE ANGLE: 62
HOLE ANGLE THRU KUP: 44
LAST TAG DATE: 11/22/87
RATHOLE: 23
FISH/OBSTRUCTION:
deg
deg
DEPTH
1200
5000
9139
PBTD:
PBTDSS:
9281
6433
:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::
:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::
STN
1
2
3
5
7
8
INTERVAL
9084-9116
GAS LIFT and FLOW INFORMATION
VALVE
DEPTH MANDREL SIZE
2908 MERLA 1"
5413 MERLA 1"
6528 MERLA 1"
7042 MERLA 1"
7523 MERLA 1"
7973 MERLA 1"
8455 MERLA 1"
8873 OTIS 1.5"
PORT
SIZE
o.188
.DV
0.188
.DV
.DV
.DV
0.188
0.25
PERFORATION DATA
ZONE FT SPF PHASE COMMENTS
A1 32 12 120 5" CSG GUN
RECEIVED
OCT 2 1992
Alas~ .0it & Gas Cons..6ommissioa
'Anclioragm
REVISION DATE: 10/20/92
REASON: P RE-CONVE RS ION
.~, ~ STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION Cu,viMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name. of Operator 7. Permit Number
ARCO Alaska, Inc. 86-193
3. Address 8. APl Number
P. 0. Box 100360, Anchoraae, AK 99510 50- n~q-~
4. Location of well at surface 9. Unit or Lease Name
2241' FNL, 2207' FEL, Sec.17, T13N, R9E, UM ~ ....... ~ P~,,,~r Unit
At Top Producing Interval 10'.'~-el-I' I~'m'l~r' v _
1128' FSL, 1608' FEL, Sec. 7, T13N, R9E, UM 3Q-8
At Total Depth 11. Field and Pool
1189' FSL. 1823' FEL. See. 7¢ TI_~N; RgF, IIM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River
0i
1
Pool
RKB 60'I Anl ~024 ALK 3574
12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore i16. No. of Completions
01/12/87 01/17/87 05/19/87'] N/A feet MSLJ 1
'"17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
9400'MD, 6579'TVD 9281 'MD, 6493'TVD YES [~ NO []I 1812' feet MD 1600' (approx.)
22. Type Electric or Other Logs Run
DIFL/SFL/GR, FDC/CNL/Cal, CBL/CCL/GR, Gyro
"23. CASING, LINER AND CEMENTING RECORD
m
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 1875# Pol eset
9-5/8" 36.0# J-55 Surf 4935' 12-1/4" 1200 sx AS IV & 325 sx (:lass G
7" 26.0# J-55 Surf 9361' 8-1/2" 630 sx Class G & 175 sD AS I
24. Perforations open to Production (MD+TVD of Top and Bottom and 2,5. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
9084'-9116'MD 6349'-6373 'TVD 2-7/8" 9005' 8941 '
Perforated w/12 spf, 120° phasing
26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
See attached Adden,~um~ dated 5/22/87,
for fractljre data
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [GAS-OILRATIO
TEST PERIOD II~
Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE I~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
.
* NOTE: Drilled RR 1/19/87. Perforated well & ran tubino 3/1/87.
Form 10-407 WC3/7 :DAN I Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. . 30. {
·
GEOLOGIC MARI~I~RS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 9074' 6343' N/A
Base Kuparuk C 9088' 6353'
Top Kuparuk A 9088' 6353'
Base Kuparuk A 9160' 6405'
31. LIST OF ATTACHMENTS
Addendums (dated 3/24/87 & 5/22/87)
32. I hereby certify that the foregoing is true and Correct to the best of mY knowledge
~.~/~) ~.j_,L./,Lg/'t Associate Engineer ~-
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injectiOn, observation, injection for in-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
ADDENDUM
WELL:
1/21/87
5/19/87
3Q-8
Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak.
Frac Kuparuk "A" sand perfs 9084'-9116' in 12 stages per
frac procedure dated 5/13/87 as follows:
Stage 1: 40 bbls 145° hot diesel 10% Musol @ 5 BPM, 4500
-~900 psi
Stage 2: Pad "A" - 90 bbls gel diesel @ 5 - 20 B?M, 3900
- 5750 psi
Stage 3: Pad "A" - 15 bbls gel diesel @ 15 BPM, 5750 -
4600 psi
Stage 4: Pad "B" - 280 bbls gel diesel @ 20 BPM, 2700 -
5200 psi
Stage 5: 20 bbls gel diesel 2# 16/20 @ 20 BPM, 5200 -
4850 psi
Stage 6: 40 bbls gel diesel 4# 16/20 18-20 BPM, 4850 -
5330 psi
Stage 7: 40 bbls gel diesel 6# 16/20 @ 18-20 BPM, 5330 -
5360 psi
Stage 8: 40 bbls gel diesel 7# 16/20 @ 18-20 BPM, 5360 -
5300 psi
Stage 9: 20 bbls gel diesel 8# 16/20 @ 18-20 BPM, 5300-
5430 psi
Stage 10:10 bbls gel diesel 9# 16/20 @ 18-20 BPM, 5430 -
5280 psi
Stage 11:9 bbls gel diesel 10# 16-20 @ 18-20 BPM, 5280 -
5390 psi
Stage 12: Flush - 26 bbls gel diesel @ 18-20 BPM, 5390 -
8500 psi
Screened out after pmp'g 26 bbls flush @ 8500 psi.
Release to Production.
Fluid to Recover:
Sand in Zone:
Sand in Csg:
Avg Pressure:
630 bbls
31,400# 16/20
8600# 16/20
5000 psi
· grilling Supervisor
' Da'ts
ADDENDUM
WELL:
2/16/87
2/17/87
3Q-8
RU Gearhart, rn 6-1/8" GR/JB to 9272'; no ice plug.
RU Schl, rn CBL/CCL/GR f/9264'-6195'. Rn gyro.
Drilli~upe~isor~
~UB-$URFACE
DIRECTIONAL
~URVEY
[~UIDANCE
~ONTINUOUS
~OOL
Company ARCO ALASKA, I NC.
Well Name 3(~~8(2241' FNLz2,207' FEL,SEC
Flo~dJLocatloll KUPARUK~ NORTH SLOPE~ ALASKA
Jcl3 Reference No.
72220
MCBRIDE
RECEIVED
Oil & Gas Cons. Com,,~,.,o,~
17,T13N,RgE,UM)
Date
16-FEB-87
Computed
HALSTEAD
SCHLUMBEROER
O I RECT I ONAL SURVEY
COMPANY ARCO ALASKA, INC.
WELL 30-8
F I ELD KUPARUK
COUNTRY NORTH SLOPE, AK
RUN
DATE LOGGED 16 - FEB - 87
REFERENCE ?2220
RECEIVED
M~ 1 9
Oil & Gas
OCT OIR~CTIOhAL SUrVeY
CUSTGHER LISTING
~'3R
ARCO ALASKA, iNC.
3i.- B
KUPARUK
NORTH SLOPE,ALASKA
SURVEY DATE: 16 FEB 87
ENGINEER: MCBRIDE
METHODS C."~~ COMPUTaTiON ~'~.'
TOOL LCCATION: TANGENTIAL- AVERAGEO DEVIATION AND AZIMUTH
INTERPOLATION: LINEAR '
VERTICAL SECTION: HORIZ, DiST, PROJECTED ONTO A..T.ARGET AZIMUTH OF NORT~ 53 O~G 34 MIN WEST
COMPUTATION DATE;
ARCO ALASKA, INC.
3Q-8
KUPARUK
NORTH SLOPE,ALASkA
INTERPOLATED VALUES POW eVEN 100
MEASU
DEF
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
3100
3200
3300
3400
3500
3600
3700
3800
3900
TRUE SUB-SEA.
RED VERTICAL VERTICAL
TH OEPTH DEPTH
.00 0.00 -60.00
· 00 100.00 40.00
· 00 200.00 140.00~
· 00 300.00 240.00
· 00 399.99 339.99
.00 499,98 439,98
· 00 599.97 539.97
.00 &99.96 639.96
.00 799.94 739.94
· 00 899.93 839.93
· 00 999.89 939.89
.00 1099.56 1039.56
· 00 1198.50 1138.50
.00 1296.28 1236.28
· 00 1392,82 133g.82
.00 1487.76 1427.76
· 00 1580.56 1520.56
.00 1671.4~ 1611.44
· 00 1759.~4 1699.94
.00 1845.58 1785.58
.00 1928.10 lS68.10
.00 2007.53 1947.53
· 00 ~84.16 2024.16
.00 ~57.09 2097.09
.00 2~27.05 2157
.oo
· 00 2~27 67 32
.oo z
,00 ~7 57,37
.oo
.00 z' 39.87
.00 2~0 Z~00.54
· 00 29~0.49 2860.49
.00 29~9.77 2919.77
· 00 30~9, '96 2979.~6
.00 3100.92 3040.92
.00 3162.95 ~102.95
'. COURSE VERTICAL
DEVIATION AZiNUIm S£CTiON
-OEE~MIN O~G MiN E~T
0 0 N 0 0 ~ 0.00
0 12 N 48 1J ~ -0.03
0:13 N 61 27 a -0.13
. 0 26 N 79 25 c -0,54
70 39 N 51 39 ~ -0.99
O 45 N 30 59 E -1.04
0 58 N 26 35 E -0,83
0 57 N 24 ~5 E -0.45
0 57 N 29 2 E -0.1~
i I N 26 10 c 0.06
2 46 N 36 ~4 w 1.98
6 18 N 49 ~3 ~ 9.79
10 18 N 51 3~ W 24.09
13 49 N 52 !0 w 44.96
i6 21 N 53 55 W 71.03
20 16 N 53 28 W 102.36
23 9 N 53 15 W 139.56
2~ ~ N 53 ~4 ~ ldl.27
2~ 20 N 51 49 W 227.79
32 56 N 50 24 ~ 279.33
35 50 N 49 2' W 335.68
38 45 N 50 57 W 396.28
41 28 N 51 59 ~ 460.47
44 25 N 50 5~ ~ 528.82
46 45 N ~ 55 ~ 600.17
47 41 N 48 5b W 573.48
48 30 N 48 38 h 747.63
49 21 N 48 30 W 822.75
50 16 N 4:5 15 W 898.~6
5i 3 N 47 59 W 9?5.87
52 2 N 47 35 W 1053.78
52 48 N 47 ~ ~ 1132.59
52 29 N 4~ 0 W 1211.83
52 24 N ~8 39 W 1290.64
52 54 N 47 5'2 W 1369.79
53 26 N 47 25 W 1449.40
5'2 26 N 46 i4 W 1529,39
52 48 N ~4 58 W 1608.47
51 54 N 43 ~8 W 1686.73
51 36 N 43 10 W 1763.90
il-MAR-87
FEET OF
DOGLEG
SEVERITY
C~G/IO0
0.00
0.14
0,36
0.19
0.36
0.26
0,17
0,21
0,13
0,38
3,75
3.48
4.11
3.55
3.05
3,84
2.82
3.12
3.23
3.4~
3.37
2.76
3,90
2,21
1,71
0.83
0.85
0.96
0.98
0.91
0.94
0.92
2.22
0.75
0.66,
0'.77
1.85
0.90
1.,
0~82
P ~ G E .1
DATE OF SURVEY: 16 FEB 87
KELLY EUSHING ELEVATION: 60.00 iff
ENGINEER: MC~RIDE
MEASbRED D~PTH
RECTANGULAR
NORTH/SCUTH
PEET
0.00 N
0.13 N
0.35 N
0.40 N
0.82 N
1.74 N
3.09 N
4.64 N
6.10 N
7.61 N
10.08 N
15.47 N
24.44 N
37.38 N
53.07 N
71,53 N
$3,76 N
118,49 N
146,55 N
178,95 N
215.39 N
254,55 N
294.27 N
336.86 N
382.34 N
~30.17 N
~79,24 N
529,12 N
579,86 N
631.50 N
684.11 N
737,75 N
791,89 N
844,16 N
897.13 N
951,07 N
1006,05 N
1061.97 N
1118,59 N
1175,68 N
COOR
EAST
FEE
O.
O.
O.
O.
1.
2.
3.
3.
4.
5.
4.
O.
11.
28.
49.
74.
104.
137,
174,
215.
258.
304.
355.
408.
463.
519.
575.
632.
689.
746.
804.
863.
921,
981.
1040.
1099.
1158.
1215.
1270.
1324,
DINATES HO~I,:Z. :~OE PARTUR E
/WEST DIST'" 'AZIMUTH
T F E E'T::!i "::. :; '"D E G M i N
o o E o.00 o o
41 E O:5~'::,.,~,:::N 49 49
96 E 1.0~:: .N- 67 31
83 E 2.01'~ N~,,~65 59
58 E 3.1,2 N:' 55 58
30 E 4.52 N 46 57
99 E 6.12 N 40 40
T3 E 7.72 N 37 47
54 ~ 9.41 N 36 3
98 E 11.24 N 26 18 E
75 W 15,48 N 2 46 W
90 W 27.18 N 25 58 W
29 W 46.87 N 37 7 W
11 W 72.30 N 42 46 W
43 W 103,23 N 46 8 W
28 W 140.23 N 48 2 W
84 W 181.77 N 49 19 W
95 W 228.22 N 50 2 W
10 W 279.80 N 50 14 ~
23 W 336,27 N 50 10 W
65 W 396.99 N 50 7 W
11 W 461,19 N 50 21 W
63 W 529.58 N 50 29 W
74 W 601.03 N 50 29 W
55 W 674.52 N 50 22 W
50 W 748,91 N 50 12 W
05 W 824.29 N 50 3 W
19 W 900.68 N 49 55 W
79 W 978,00 N 49 46 W
80 W 1056.27 N 49 38 W
15 w 1135.47 N 49 28 W
68 W 1215.15 N 49 19 W
O~ W 1°94~ .25 N 49 17 W
33 W 1373,72 N 49 13 W
46 W 1453.73 N 49 8 W
30 W 1534,Z1 N 49 1 W
31 W 1613,93 N 48 51 W
78 W 1692.97 N 48 38 W
57 W 1771.08 N 48 24 W
C'~H PUT AT Z ON
ARCO ALASKA, iNC.
KUPARUK
NORTH SLOPE,ALASkA
INTERPCLATED VALUES FOR
ME
ASURED
DEPTH
000.00
100.00
200.00
300.00
400.00
500.00
500.00
700.00
800.00
900.00
TRUE SUB-SEA
VERTICAL VERTICAL
DEPTH OEPTH
3224.99 3164.99
3285.83 3225.83
3345.00 3285.00
3402.28 3342.28
3457.59 3397.59
3511.11 3451.11
3562.94 3502.94
3613.23 3553.23
3662.45 3602.45
3710.30 3650.30
COURSE
DEVIAIION
54 23
55, 43
57 5
58 ! 1
59 21
60 12
60 53
61 53
OAT~: il-MAR-87
EVeN 100 FEFT OF
000
100
200
3OO
4O0
50O
6OO
7O0
8OO
9O0
.00
.00
.00
.00
.00
.00
.,00
.00
.00
.00
3756.87 3696.87
3803.24 3743.24
3851.40 3791.40
3901.54 3841.54
3954.29 3894.29
4008.58 3948.68
4066.20 4006.20
4124,40 4064.40
4185.42 4125.42
4247.05 4187.05
62 25
62 9
6O 15
59 5
57 51
55 40
54 ,0
53 35
51 53
52 2
¥aRTiC~L
AZIMUTm SECTION
DEG MIN FEET
000
100
200
300
400
500
600
700
800
900
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
4308.52 4248.5a
4369.99 4309.99
4431.50 4371.50
4492.96 4432.98
4554.31 4494.31
4617.67 4557.67
4681.46 4621.46
4745.27 4b~5.27
4809.20 4749.20
~872.93 4812.93
N 46 1~ W 1841.33
N 47 23 W 1920.20
N 47 15 W 2000.34
N 46 55 W 2081.78
N 46 48 W 2164.51
N 46 28 ~ 2248.37
N 46 4 ~ 2333.20
N 45 44 W 2418.87
N 45 18 W 2505.05
N 45 10 W 2591.94
000
100
200
300
400
500
600
700
800
900
· 00 4936.75 4876.75
· 00 5000.58 4940.58
,00 5064.41 5004.41
· 00 5128.56 506~.56
· 00 5195.56 5135.56
· 00 5263.16 5203.16
.00 5330,66 5270.66
· 00 5398.15 5338.15
.00 5465.75 5405.75
· 00 5533.24 5473.~4
N 45 20 W 2679.50
N 45 45 w 2707.23
N 47 Z6 W 2854.19
N 48 37 W 2940.29
N 50 4 w 3025.03
N 51 49 W 3108.83
N 52 25 W 3190.61
N 52 5e W 3271.91
N 53 ~ ~ 335!.13
N 54 5 w 3429.88
52 6 N 54 25 W 350~.75
52 1 N 54 44 W 3587.61
52 4 N 55 5 W 366~.43
52 9 N 55 24 W 3745.27
51 35 N ~6 50 W 3824.19
50 22 N 58 ~$ ~ 3901.30
50 18 N 59 3 W 3977.97
50 17 N 59 20 W ~054.5~
50 18 N 59 33 W 4131.08
50 2~ N 59 49 W 4207.71
50 21 N 60 10 W 4284.21
50 16 N 60 33 W 4360.65
50 1~ N 61 7 W ~437.00
49 15 N 61 ~7 W 4512.99
47 26 N 62 24 ~ 4586.40
47 26 N 63 1 W 4659.15
~7 35 N 63 35 W 4731.86
47 32 N 64 9 W 4804.46
47 31 N 64 44 W 4876.82
47 38 N 65 25 W 4949.13
DOGLEG
SEVERITY
BEG/lO0
3.20
1.20
1.44
1.49
1.30
1.34
1.lb
0.92
1.07
1.05
0.64
1.17
I .31
3.50
1.00
3.18
0.52
3.10
0,40
0.38
0.25
0.32
0.34
0.61
3.78
0.31
0.18
0.71
0.38
0.52
0.34
0,47
0.49
3,41
0., 53
0
0,58
0'. 51
PAGE 2
OAT~ OF SURVEY: 16 FEB 87
KELLY 60SHING ELEVATION: 60.00 E1
ENGINEER: MCBRIDE
MEASURED DEPTH
RECTANGULAR COORDINATES HORIZ. DEPARTURE
NORTH/SOUTH EAST/WEST DIST..· A:ZIMOTH
FEET FE~T FEET' : DEG MIN
·
1231.69 N I379.46 W 1849.~ N 48 14 W
1285.56 N I437.73 W I928.6~N 48 li ~
i340.19 N i497.00 W 2009.__26'~: ~. 48 9 W
1395.99 N 1~57.04 W 2091'Zzi.-48 7 W
1452.98 N 1617.81 W 2174,50':~ ::N 48 4 W
1510.94 N 1679.26 W 2258.-95,N 48 1W
1570.06 N 1741.04 W 2344.42 N 47 57 W
1630.13 N 1803.19 W 2430.81 N 47 53 W
1691.17 N 1865.25 W 2517,78 N 47 48 W
1752.97 N 1927.63 W 2605.51 N 47 43 W
2342.90 N 2~31.70 W 3523.49 N 48 19 W
2388.61 N 2695.9~ W 3601.91 N 48 27 W
2433.92 N 2760.50 W ~680.26 N 43 35 W
2478.89 N 2825.30 W 3758,bl N 48 44 W
2523.31 N 2890.60 W 3837.01 N 48 52 W
2564.07 N 2956.35 W 3913.3'? N 49 3 W
2603.80 N 3022.32 W 3989,27 N 49 15 W
2643.24 N 3088.45 W 4065.12 N 49 26 W
2682.33 N 3154.66 W 4140.87 N 49 37 W
2721.24 N 3221.1~ W 4216.?? N 49 48 W
2759.74 N 3287.85 W 4292.57 N 49 59 W
2797.80 N 3354.76 W 4368.31 N 50 10 W
2835.28 N 3422.00 W 4443.97 N 50 21 W
2871.96 N 3489.3? W 4519.28 N 50 32 W
2906.68 N 3554.98 W 4592,02 N 50 43 W
2940.46 N 3620.4~ W 4664.13 N 50 55 W
2973,58 N 3686,40 W 4736.Z2 N 51 6 W
3000.07 N 3752.65 W 4808.20 N 51 18 W
3037.86 N 3819.12 W 4879.99 N 51 30 W
3068.96 N 3886.05 W 4951.76 N 51 42 W
COMPUTATION D~TE:
ARCO ALASKA, INC.
3Q-8
KUPARUK
NORTH SLOPE,ALASKA
11-MAR-87
ME4SURED
DEPTH
INTERPOLATED VALUES F3R kVEN 100 FEET OF
O0
10
20
30
4O
50
60
70
80
90
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
TRUE SUB-SEA COURS:
VERTICAL VERTICAL DEVIATION AZIMUTH SE
DEPTH DEPTH. OEG MIN DEG ~IN
O0
10
20
30
40
0.00
0.00
0.00
0.00
0.00
5600,70 5540,70 .47 26 N 65 b w 50
5668.35 5608.35 47 27 N 66 39 W' 50
5735.91 5675,91 !47 29 N 66 5~ W 51
5803,66 5743,66 47 9 N 67 35 W 52
5871.~6 5811.86 46 57 N 6S 17 W 53
5940,08 5860.08 47 ' 0 N 6~ 3 W 53
6008.50 5948,50 46' 35 N 70 5 W 54
6077,38 6017.35 W6 8 N 71 3 W 55
6147;21 6087.21 45 21 N 72 0 W 55
6217,89 6157,89 44 45 N 72 48 W 56
6289.35 6229.35 44 6 N 73 29 W 57
6361.42 6301.42 43 40 N 74 0 W 57
6433,90 6373,90 43 28 N 74 5 W 58
6506,~2 6446,6~ 43 21 N 74 11 W 59
6579,33 6519.33 43 21 N 74 11 W 59
TZCAL COGLEG
CTION SEVERITY
FEET CEG/IO0
21.29 0.57
93.09 0,36
64.86 0,39
35.32 0,62
07,19 0,87
77.76 0.70
47.87 1.01
i7.19 1.30
85.29 1.00
52.23 0.79
18.16 0,90
83.19 0,68
47,73 0,79
11,97 0.00
76,23 0,00
DATE OF SURVEY: 16 FEB 87
KELLY BUSH1NG ~LEVAT£ON: 60.00 FT
ENGIN:~R: MCBRIDE
MEASbRED DEPTH
RECTANGULAR COORDINATES HORIZ. DEPARTURE
NORTH/SOUTH EAST/WEST DIST..' AZIMUTH
FE~T FEET FEET DEG MIN
3099.27 N 3953.36 W 5023,40 ':N 51 54 W
3128.72 N 4020,86 W 5094,73 N 52 6 w
3157,79 N 4088.61 W 5166o08 N 52 19 W
31~6.23 N 4156,44 W 52~7o1~i N 52 31 W
3213.78 N 4224.19 W 530?°75 .N 52 ~4 W
3240,32 N 4292,31 W 53/8o,07 N 52 57 W
3265,83 N 4360,63 W 5448,01 N 53 10 W
3289,92 N 4429,01 W 5517,22 N 53 ~3 W
3312,63 N 4496,89 W 5585,30 N 53 37 W
3333,98 N 4564,33 W 5652,30 N 53 51 W
3354,27 N 4631,29 W 5718.39 N 54 5 W
3373,58 N 4697,87 W b783,6~ N 54 19 W
3392,54 N 4764,09 W 5848,58 N 54 32 W
3411,25 N 4830,13 W ~913,28 N 54 46 W
3429,97 N 4896,18 W 5978,07 N 54 59 W
COHPUTATZON
ARCO ALASKA, INC.
3Q-8
KUPARUK
NORTM SLOPE,ALASKA
INTERPOLATED VALUES FOR
MEASURED
DEPTH
TRUE SUb-SEA COURSE
VERTICAL VERTICAL~.DE¥IATION AZZMUTn
DEPTH DEPTH'' OEO MIN OEO ~IN
0.00 0.00
1000.00 999.89
2000.00 1928.10
3000.00 2617.37
4000.00 3224.99
5000.00 3756.87
6000.00 4308.52
7000.00 4936.75
8000.00 5600.70
9000.00 6289.35
DATE: Il-MAR-87
EVEN 1000 FSET OF
VERTICAL COGLEG
SECTION SEVERITY
FEET CEO/lO0
-60.00 0 0 N 0 0 E 0.00
93~.89 2 46 N 36 44 ~
1868.10 ~35.50 N 49 23 W 335.68
2557.37 52 2 N 47 35 w 1053.75
3164.99 51 57 N 46 19 W 1641.33
3696.87 62 25 N 45 20 w 2679.50
4248.52 52 6 N 54 25 W 5508.75
4876.75 50 21 N 60 10 W 4284.21
5540.70 47 26 N 66 6 W 5021.29
6229.35 44 6 N 73 29 w 5718.16
9400.00 a579.33 6519.33 43 21 N 74 11 W 5976.23
0.00
3.75
3.37
0.94
3.20
0.64
0.25
0.34
0.57
0.90
0.00
KELLY
DATE OF SURVEY:
~USHING ELEVATION:
ENGINEER:
PAGE
i6 FES
60,00
MCBRIDE
MEASUREb DEPTH
RECTANGULAR COORDINATES HO~IZ, DEPARTURE
NORTH/SOUTH EAST/WEST GIST~.' AZIMUTH
FEET FE~T FE'~'..~~ OEG MIN
0.00 N 0.00 E 0.0:0 N 0 0 E
10.08 N 4.98 E- ll-,Z~ ,N?Z6 18 E
215.3~ N 258.23 W 336;27 ,]~N"'50 10 w
664.11 N 804.80 W 1056.27 N' ~9 38 W
1231.69 N 1379.46 W 1849.3I..~'.,N 48 1~ ~
1815.29 N 1990.40 w 2693.gz,,".~N. 47 3~ W
2342.90 N 2631.70 W 3523.49 N 48 19 W
2759.74 N 3287.85 W 4292.57 N 49 59 W
3099.27 N 3953.36 W 5023.40 N 51 54 W
3354.27 N 4631.29 W 5718.39 N 54 5 W
3429.97 N 4896.1B W 5978,07 N 54 59 W
ARCO ALASKA, iNC.
3Q-8
KUPARUK
NORTH SLOPE,ALASKA
TRUE
MEASUREO VERTICAL
DEPTH DEPTH
0.00 0.00
60.00 60.00
160.00 160.00
260.00 260.00
360.00 360.00
460.01 460.00
560.02 560.00
660.04 660.00
T60.05 760.00
860.06 860.00
960.08 960.00
1060.25 1060.00
1160.95 1160.00
1262.74 1260,00
1365.88 1360.00
1470.52 1460.00
1577.'69 1560.00
1687.26 1660.00
1800.07 1760.00
1917.26 1860.0C
2039.67 1960.00
2168.03 2060.00
2304.07 2160.00
2448.41 2260.00
2597.52 2360.00
2750.43 2460.00
2907.66 2560.00
3069.73 2660.00
3234.85 2760.00
3399.10 2860.00
3566.64 2960.00
3733.12 3060.00
3895.24 3160.00
4057.25 3260.00
4225.85 3360.00
4404,44 3460,00
4594.26 3560.00
4794.96 3660,00
5006.78 3760.00
5217.26 3860.00
COMPUTATION BATE:
INTERPOLATED VALUES FUR EV"N 100
SUB-SEA COURSE VaRTiC~L
VERTICAL DEVIATION AZIMUTH SECTICN
DEPTH DEG MIN D~G ~iN FEET
-~0.00 O. 0 N 0 8 E 0.00
0.00 0 19 N 42 31 E 0.00
100.00 0 12 N 53 13 : -0.08
200.00 0'~20 S 89 33 ~ -0.33
300,00 0 ~5 N 62 32 ~ -0.83
400.00 0 40 N 35 17 ~ -1.08
500.00 0 53 N 27 9 ~ -0.9~
600.00 0 59 N 22 3~ E -0.61
700.00 0 56 N 27 14 ~ -0.28
800.00 0 59 N 27 33 E 0.04
900.00 1 37 N 14 54 W 0.61
1000.00 4 52 N 47 W4 W 5.94
1100.00 8 39 N 51 29 W 17.62
1200.00 12 27 N 51 42 W 36.51
1300,00 15 27 N 53 14 W 61,68
1400.00 19 10 N 53 ~9 W 92.43
1500.00 22 34 N 53 20 W 130.92
1600.00 25 45 N 53 48 W 175.67
1700.00 2~. 20 N 51 49 W 227,82
1~00.00 33 26 N 50 10 W 288.81
1900.00 37 9 N 49 31 W 359.19
2000.00 40 23 N 52 2 W 439.55
2100.00 44 30 N 50 56 W 531,66
2200.00 ~7 18 N 49 '25 W 6,35.55
2300.00 48 29 N 48 38 ~ 745.78
2400.00 49 50 N 48 :25 W 861.01
2500.00 51 7 N 47 5~ W 981.80
2600.00 52 34 N 47 19 W 1108.66
2700.00 52 1~ N 46 36 ~ '1239.29
2800.00 52 53 N 47 52 ~ 1369.07
2900.00 53 41 N 46 ~S W 1502.73
3000.00 52 35 N 44 36 ~ 1634.53
3100.00 51 36 N 43 9 W 1760.24
3200.00 52 36 N ~7 21 W 1886.33
3300.00 54 44 N 47 10 W 2021.27
3400.00 57 8 N 46 ~8 W 2168.22
3500.00 59 17 N 46 5 W 2328.~0
3600.00 60 49 N ~5 18 W 2500.69
3700,00 62 25 N 45 20 W 2685,45
3800.00 60 9 N 47 36 W 2869,08
il-MAR-87
KELLY
DATF
BUSHING
OF SURVE¥:
ELEVATION:
ENGINEER:
PAGE
16 FE~
60.00 Fi
MCSRIOE
FEET OF SUB-SEA ~:EPT~.
£O'3LEG RECTANGULAR
SEVERITY NDRTH/SOUTm
BEG/lDO FEET
COOROINATES
EAST/WEST
FE~T
HORIZ...DEPAR
diST. '.:AZIMU
F~ET ,,,DEG M
0.00 0.00 N 0.00 ~ 0.00
0.70 0.02 N 0.02 e 0.02
0.18 O.2b N 0.29
0.55 0.36 N 0.68 E 0.77
0.37 0.58 N 1.46 E 1.57
0.28 1.32 N 2.3Z E 2.67
0.32 2.50 N 3.00 k 3.90
0.06 4.01 N 3.72 ~ 5.47
0.09 5.52 N 4.42 E 7.07
0.18 6.98 N 5.21 E 8.71
3.12 8.78 N 5.72 E 10.
3.66 12.93 N 2.16 E 13.
4.42 20.42 N 6.8J W 21.
3.61 32.16 N 21.6~ W
2.62 47.53 N 41.58 W 63.
3.87 65.64 N 66.43 W 93.
2.39 88.59 N 97.34 W 131,
3.11 115.18 N 133.32 W 176.
3.23 146.57 N 174.98 W 228.
2,84 185.02 N 222.40 W 289.
77 N 276.11 W 359.
41 N 338.60 W 440.
65 N 410.84 W 532.
28 N 490.78 W 636.
O1 N 574.11 W 747.
59 N 660.79 W 862.
48 N 751.21 W 983.
41 N 845.47 W 1111.
20 N 942.30 W 1242.
64 N 1039.79 W 1373,
3.36 230.
2.90 281.
2.28 338.
1.25 405.
0.85 478.
0.88 554.
0.97 635.
0.89 721.
0,'72 810.
0.66 896.
1,33 987.56 N 1138.81 W 1507.
1,20 1080.68 N 1233.89 W 1640.
0.74 1172.95 N 1322,03 W 1767.
1,18 1262.50 N 1412,65 W 1894.
1.26 1354,50 N 1512.46 W 2030.
1-24 1455.53 N 1620.53 W 2178.
1.,~9 1566.64 N 1737.~9 W 2339.
1'04 1688.07 N 1862.11 W 2513.
1819.52 N 1994.74 ~ 2699.
1947.72 N 2128.34 W 2885.
N 0
N 42 3
N 49
68 2
.N 60 1
N'50 1
N 42 4
N 38 4
N 36 4
43 N 33
11 N 9
53 N 18
76 N 33
15 N 41
39 N 45
61 N 47
19 N 49
25 N 50
30 N 50
85
28
42
49
O6
68
95
72
O0
N 50
N 50
N 50
N 50
N 50
N 49
N 49
N 49
N 49
N 49
TURE
TH
IN
3 ~Z
7 ~
9 E
5 ~
7 ~
8 E
2 E
1 ~
4
29
29
55
10
20
41
10
2
14
6
16
30
27
13
59
46
31
18
13
37 N 49 4
Z3 N 48 47
36 N 48 25
59 N 48 12
32 N 48 9
23 N 48 4
49 N 47 57
37 N 47 48
93 N 47 37
03 N 47 32
W
W
W
W
W
W
W .
w
COMPUTATION
ARCO ALASKA, INC.
3Q-8
KUPARUK
NORTH SLOPE,ALASKA
OATE: Il-MAR-S?
TRUE
MEASURED VERTICAL
DEPTH DEPTH
3410.77 3960.00
5589.26 4060.00
5738.84 4160.00
3921.06 4260.00
6083.76 4360.00
6246.39 4460.00
6409.12 ~560.00
6566.41 4660.00
6723.02 4760.00
68?9.70 4860.00
DATE
KELLY 5USHING
INTERPOLATED VALUtS FOR EVEN 100 FEET OF SUB-SEA DEPTH
SUB-SEA-
VERTICAL DEVIATION
COURSE VERTICAL COG
AZiNUTM SECTION SEV
DEG MIN FEET DEG
N 50 9 W 3034.14
N 32 23 w 3181.85
N 53 29 ~ 3318.76
N 54 9 ~ 3446.49
N 54 41 W 3574.81
N 55 13 W 3703.03
N 57 8 W 3831.31
N 58 59 W 3952.2~
N 59 23 W 4072.20
N 59 ~4 W 4192.15
7036.42 4960.00
7193.09 5060.00
7347.41 5160-00
7495.33 5260.00
7643.50 5360.00
7791.48 5460.00
7939,80 5560.00
8087.66 5660.00
8235.63 5760.00
8382.62 5860.00
8329.17 5960.00
8674.85 6060.00
8818.17 6160.00
8959.08 6260.00
9098.04 6360.00
9235.85 6460.00
9373.41 6560.00
9400.00 6579.33
DEPTH' DEG MIN
3900.00 57 49
~000.00 54 40
4100.00 52 6
4200.00 52 4
4300.00 52 2
4400.00 52 2
4500.00 51 23
4600.00 50 20
4700.00 50 14
~800.00 50 27
N 60 19 W 4312.06
N 61 5 W 4431.74
N 62 5 W 4548.09
N 62 59 W 4655.76
N 63 bl W 4763.48
N 64 41 W 4870.66
N 65 41 W ~977.96
N 66 36 N 5084.24
N 67 8 W 5190.39
N 6~ o W 5294.89
N 69 17 ~ 5398.29
N 70 ~ W 5499.85
N 72 9 W 5597.53
N 73 12 w 5691.31
hi 74 il W 5~70.75
N 14 1i W 5959.14
N 74 i1 ~ 597~.23
4900.00 50 19
5000.00 50 19
5100.00 47 49
5200.00 47 26
5300.00 47 32
5400.00 47 29
5500.00 47 38
5600.00 47 27
5700.00 47 24
5800.00 46 57
LEG RECTANGULAR
ERITY NORTH/SOUTH
/100 FEET
1.21 2056.62
0.3a 2148.52
1.84 2231.28
0.30 2306.57
0.26 2381.21
0.63 2454.84
3.82 2527.18
0.36 2590.50
0.63 2652.25
0.58 2713.37
0.34 2773.66
0.47 2832.72
2.27 2888.64
0.49 2938.90
0.48 2987.79
0.64 3035.18
1.39 3081.17
0.40 3125.12
0.~9 3168.05
0.79 3209.05
0.63 3247.91
0.85 3284.00
0.97 3316.58
0.98 3346.06
0.65 3373.21
0.00 3399.26
0.00 3424.99
0.00 3429.97
5900.00 4a 57
6000.00 46 21
6100.00 45 13
6200.00 44 18
6500.00 43 40
C400.00 43 21
6~00.00 43 21
6519.33 4~ 21
OF SURVEY:
ELEVATION:
ENGINEER:
PAGE
16 FEB
60.00
MCBRIDE
6
87
FI'
COORDINATES H
EAST/WEST OI
FEET FE
N 2253.11 W 3050
N 2368.86 W 3198
N 2477.94 W 3334
N 2581.13 W 3461
N 2685.53 W 3589
N 2790.54 W 3716
Iq 2896.59 W 3844
N 3000.16 W 3963
N 3103.68 W 4082
N 3207.66 W 4201
ORIZ. DEPARTURE
AZIMUTH
ET.'%. DEG MIN
.6i N'47 3a W
.0~ N 47 47 W
.49 N47 59 W
.58 N 48 12 w
o18 ,N 48 26 w
.63 ~'N 48 39 w
.07 N 45 53 W
.79 N 49 11 W
.55 N 49 29 W
.36 N 49 46 W
N 3312.19 W 4320.16 N 50 3 W
N 3417.35 W 4438.76 N 50 20 W
N 3520.69 W 4554.05 N 50 37 W
N 3617.41 W ~660.77 N 50 54 W
N 3715.20 W 4767.56 N 51 11 W
N 3813.44 W 4873.88 N 51 28 W
N 3912.87 W 4980.38 N 51 46 W
N 4012.52 W 5085.93 N 52 5 W
N 4112.78 W 5191.48 N 52 23 W
N 4212.39 W 5~95.49 N 52 4i W
N 4312.24 W 5398.54 N 53 0 W
N 4411.83 W 54~9.90 N 53 20 W
N 4509.18 W 5597.53 N 53 39 W
N 4603.97 W 5691.47 N 53 59 W
N 4696.56 W 5782.40 N 54 18 W
N 4787.7U W 5871.78 N 54 37 W
N 4878.62 k 5960.83 N 54 55 W
N 4896.18 W 5978.07 N 54 59 W
ARCO ALASKA, INC.
3;-8
KUPARUK
NORTM SLOPE,ALASKA
MARKER
TOP KUPARUK C
BASE KUPARUK C
TOP KUPARUK A
BASE KUPARUK A
PSTD
TD
COMPUTATION
INT ER PO LA T c D
MEASURED C~PTH
BELOW Km
9074.00
908~.00
9088.00
9160.00
9281.00
9400.00
DATE:
'VALUES
11-MAR-87
FCR C~CSEN HORIZONS
O~IGIN: 2241'
TVD
FRON K6 SUB-SEA
6342.84 6282.64
6352.75 6292.75
8352.75 6292.75
6404.~8 6344.88
64~2.Sl 6~32.81
$~79.33 6519.33
KELLY
FNL,
OATE OF SURVEY:
BUSHING ~LtVATION:
ENGiNeER:
PAGE
16 FEB
60.00
MCBRIDE
SURFAC6 LOCATZON
AT
2207' FEL,
REClANGULAR .COORDIN
NQRTH/$OUT. 'EAST/
3368.62 N .... i4680.
3371.29 N. ~689.
3~.98 N 4737.
340?.70 N 4817.
3429.97 N 4896.
3N
AT~S
WEST
89 W
89 W
61 W
58 W
18 W
7
87
FT
Rgb,
ARCO ALASKA, INC.
3~-8
KUPARUK
NORTH SLOPE,ALASr<A
M&RKER
TOP KUPARUK C
BASE KUPARUK C
TOP KUPARUK A
BASE KUPARUK A
PBTD
TO
COMPUTATION i~AT E:
',~, ='- MEASURED DEPTH
-- BELO~ Km
9074.00
9088.00
9088.00
9160.00
9400.00
Il-MAR-B7
SUHMARY
FRGM KB
6342.64
6352.75
6;52 7;
~404.88
6432.81
6579.33
KELLY
O2IGiN: 2241'
TVD
SUB-SEA
6282.64
6292.75
6292.75
6344.88
6432.81
6519.33
FNL~
D~TE
BUSHING
SUR
2207~ FE
R~ TAN
NORTH
3368
3371
337i
338~
3407
3429
OF SURVEY:
kLEVATION:
ENGINEER:
PAGE
16 FEB
60.00
MCbRiDE
FACE
AT :" ~:,~i-
·
.Z9 N 46~9.89
.~a N ~73.7.~
.70 N 48I'7.58
.97 N 4896.i8
87
FT
Rgb,
FINAL
MEASURED
DEPTH
9400.00
WELL LOCATION
TRUE
VERTICAL
DEPTH
6579.33
AT TD:
SUB-SEA
VERTZCAL
OEPTH
6519.33
HORIZONTAL DEPARTURE
OISTANCE AZIMUTH
FEET OEG MIN
597~.07 N 54 59
,(
WELL:, 3Q-8 ~
(2241' FNL, 2207' FE~, SEC 17, T13N, RgE,UM)
HORIZONTAL PROJECTION
~TH S000
5000
4000
~000
] 000
- ! 000
12000
-6000
WEST
-5000 -4000 -3000 -ZOO0 - ! 000 0 1000
2000
HELL'. 3q-~
(2~' FNL, 2207' FEI SEC
VERTICAL PROJECTION
- 1ooo o o 1ooo 2000 ~ooo 4000 sooo 6ooo 7ooo
306.
...~:....; ......... ~L~i~`~L~4~.~;~i~i~.
"'?'"T"T"'T"T'"T'"T"? ....... I'"T"T'"T'"?'"T'"T'"T'"T'"T"'T"-"z'"~'"T'"T'""~'"~'".T-'T"T ................... T'"7"F'T"'T'"7'"T"""'?, ...........
l. 4.4...~...~...i...+...+...;--.;4..+-.~.-.;4..-;-...i 4...;..
}..i--.!..-!---f.i---~----i--..i.--~.-i:.~..-!-.?..--~-:!.--~---~.-.f--?.--!.--~-..~---!--f-.7.7-=?! ........... f.-?.!...~.--:..-:.--~~--~.!-~om--:...~...:-..:~:.-...~.:.,....; ..........
---~.-'~--.~ ....... · ......... ~ ......................... : ....... ?-"-r ............... T ...........
...L..i...L...:...i....~ ........ ~ .................................................................. r-'-~ ............ ~'"';'"T ........
'"?'"!'"'7'"?'"? .......... l~J" '" ~J ' r)~r~nl~'!'"~i" ~ '"?,''' '"~"'~ ............
· "~'"~"'~'"i"i"'~'"'""~'": ........ ~ ....... ~'"'~"";'":'"~'"?'"t"'"': ....... ?"'""'?":'"~
...L.~...L.;...,L..;...L..L.L.. '"r'"~"'~ ........ i'--:'": ............ i'"'"'; ............ : ..................
· --? ........ ~-...t.-,t---~ ............ ?--.1.-.~-..~ ..................................................................................................
..... : ........... ~ ....... ~ .................. ; ............ ~....: ........ ~ ..................... ! .................................... ~ rtl
..4...L..,....L..L..;....~-..~....;.4....;...~-..L..~...L.~ ........ ~....~......~ ....... ~...L..~...-;...~ ........ ;....' ....... ~...~...L..~...~....i...;.-.; ............
N
PROJECTION ON VERTICAL PLANE 306. - 126. SCALED IN VERTICRL DEPTHS HORIZ SCALE = 1/ lO00 IN/FT
STATE OF ALASKA
ALA,-- OIL AND GAS CONSERVATION CON .... SION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate j~ Pull tubing
Alter Casing [] Other ~ COMPLETE
2. Name of Operator
ARCO Alaska, Inc,
3. Address
'P.O. Box 100360 Anchorage, AK 99510-0:360
4. Location of well at surface
2241' FNL, 2207' FEL, Sec.17, T13N, RgE, UH
At top of productive interval
1128' FSL, 1608' FEL, Sec. 7, T13N, RgE, UN
At effective depth
1167' FSL, 1745' FEL, Sec. 7, T13N, R9E, UM
At total depth
1189' FSL~ 1823' FEL~ Sec. 7~ T13N~ R9E~ UM
!1. Present well condition summary
Total depth: measured 9400
true vertical 6579
Effective depth: measured 9281
true vertical 6493
Casing Length
Conductor 80'
Surface 4898'
'MD
'TVD
'MD
' TVD
Size
16"
9-5/8"
Producti on 9326 ' 7"
feet
feet
feet
feet
Datum elevation (DF or KB)
RKB §0' Feet
Unit or Property name
Kuparuk River Unit
7. Well number
3Q-8
8. Approval number
7-119 .
9. APl number
50-- ~79-71
10. Pool'
Kuparuk River Oil Pool
Plugs (measured) None
Junk (measured) None
Cemented Measured depth
1875# Poleset 115'MD
1200 sx AS IV & 4935'MD
325 sx Class G
630 sx Class G & 9361'MD
175 sx AS i
Rue Vertical depth
115'TVD
3726'TVD
6551'TVD
Perforation depth: measured
true vertical
9084 ' -9116 ' MD
6349'-6373'TVD
12.
Tubing (size, grade and measured depth)
2-7/8", L-80, tbg w/tail ~ 9005'
Packers and SSSV (type and measured depth)
HRP-1-SP pkr ~ 8941', & TRDP-1A-SSA SSSV @ 1812'
Stimulation or cement squeeze summary
N/A
Intervals treated (measured)
Treatment description including volumes used and final pressure
RECEIVED
MAR ! 9 ]987
Alaska Oil & Gas Cons. Commission
Anch0r~o
13.
N/A
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Iniection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
14. Attachments (Compl etlon Wel 1 Hi story w/Addendum, dated 02/17/87)
Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro
15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,,~_ ,,~--~'
Form 10-404 Rev. 12-1-85
Title Associate Engineer
(Dani) SW02/11
Submit in Duplicate
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
IAccounting
State
cost center code
Alaska
iWell no,
3Q-8
District County or Parish
Alaska North Slope Borough
Field Lease or Unit
Kuparuk River ADL 25512
Auth. or W.O. no. T t e
AFE AK1622 Completion
Nordic 1 API 50-029-21681
Operator
ARCO Alaska, Inc.
Spudded or W.O. begun
Complete
A.R.Co. W.I.
56.24%
Date
2/28/87
I otal number of wells (active or inactive) on this
DSt center prior to plugging and I
bandonment of this well
I
our I Prlor status if a W.O.
I
1815 hrs.
Date and depth
as of 8:00 a.m.
3/01/87
thru
3/02/87
Complete record for each day reported
7" @ 9361'
9281' PBTD, RR
6.9 ppg Diesel
Accept rig @ 1815 hrs, 2/28/87. ND tree, NU & tst BOPE to 3000
psi. RU WL, perf w/5" guns, 12 SPF, 120° phasing
f/9084'-9116', RD WL. RU & rn 274 its, 2-7/8", 6.5#, L-80 EUE
8RD AB-Mod tbg w/pkr @ 8941' SSSV @ 1812', TT @ 9005'. Tst
pkr & sSsv; OK. ND BOPE, NU & tst tree to 250/5000 psi. Displ
well w/diesel RR @ 1730 hrs, 3/1/87.
RECEIVED
MAR 1 9 !287
Aiasl<a Oil & Gas Cons. Comrais¢or!
Ar* ~iq t~ r~,;-
Old TD
Released rig
1730 hrs.
New TD
Date
3/1/87
PB Depth
Kind of rig
9281' PBTD
Rotary
Classifications (oil, gas, etc.)
Oil
Producing method
Flowing
Type completion (single, dual, etc.)
Single
Official reservoir name(s)
Kuparuk Sands
Potential test data
Well no, Date Reservoir Producing Interval Oil or ~as Test time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date
corrected
The above is correct
For form preparation and distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drilling Supervisor
ADDENDUM
WELL:
1/21/87
3Q-8
Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak.
'D ii i-ling Supervisor
z Da~e
ARCO Alaska, I;.~;~, ~
Post Off, 100360
Anchorage, ,~-aska 99510-0360
Telephone 907 276 1215
Date: February 26, 1987
Transmittal f) 5926
-RETURN TO:
ARCO Alaska, Inc.
Attn: Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
2ransmitted herewith are the following items.
and return one signed copy of this transmittal.
3Q-8 CBL 2-16-87 6195-9264
2H-6 CET 1-17-86 7400-8873
2H-5 CET 1-16-86 6525-7959
3F-13 CET 1-7-86 6160-7920
3F-12 CET 1-23-86 6946-7250
2H-8 CET 1-1-86 8000-8650
2H-7 CET 1-1-86 6800-7938
3F-14 CET 1-7-86 4700-6760
3K-5 CET 7-16-86 6988-7990
3K-3 CET 7-14-86 7595-8800
3K-4 CET 7-14-86 7793-8787
3F-12 CET 1-7-86 6050-7416
Please acknowledge receipt
// Alaska 0ii & Gas C. ons. CommisSion
Anch0mge Date
NSK , Drilling State (+ sepia) BPAE Chevron
.,
SAPC Mobil Unocal Vault (film)
ARCO Alaska, Inc, is a Subsidiary of AllanticRichfieldCompany
STATE OF ALASKA
ALA~k~...OIL AND GAS CONSERVATION COIV~¥.~ION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon [] Suspend L--] Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~
Time extension [] Change approved program [] Plugging [] Stimulate ?, Pull tubing~m Amend order ~ Perforate ..__~ Other
2. Na~Eec~f ODerator
Alaska, Inc.
3. Address
P. 0. Box 100360 Anchorage, AK 9951 0-0360
4. Location of well at surface
2241 ' FNL, 2207' FEL,' 5ec.17, T13N, R9E, UM
At top of productive interval
1272' FSL, 1686' FEL, Sec. 7, T13N, R9E, UM (approx.)
At effective depth
1156' FSL, 1741' FEL, Sec. 7, T13N, RgE, UH (approx.)
At total depth
1181, FSL, 1820' FEL, Sec. 7, T13N, RgE~ UM (approx.~)
11. Present well condition summary
Total depth: measured 9400 'ND feet Plugs (measured)
true vertical 6593 ' TVD feet
5. Datum elevation (DF or KB)
R KB 60 ' feet
6. Unit or Property name
Kuparuk River Unit
7. Well number
3Q-8
8. Permit number
86-193
9. APl number
_ 50-'n29- 216B1
10. Pool
Kuparuk River Oil
Pool
None
Effective depth: measured 9281 'MD feet Junk (measured)
true vertical 6508 ' TVD feet
None
Casing Length Size
Conductor 80' 16"
Cemented Measured depth True Vertical depth
1875# Poleset 115'ND 115'TVD
Surface 4898' 9-5/8"
Production 9326' 7"
1200 sx AS IV & 4935'MD 3734'TVD
325 sx Class G
630 sx Class G & 9361'MD 6565'TVD
175 sx Class
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
12.Attachments
WELL HISTORY
Description summary of proposal ~., Detailed operations program - BOP sketch
13. Estimated date for commencing operation
April, 1987
14.
If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed {~ ~ .~.~~_ Title Associate Engineer
Commission Use Only (DANI) 5A/218
Conditions of approval
Approved by
Date
Notify commission so representative may witness I Approval No.
~ Plug integrity ~_ BOP Test ~ Location clearanceI
":"?'i~'~:~ ...... ! -.' :;~:,.' .~Imlil!ll~' ~
'"': :';"' ~- ~ ~ - ~7 by order of
~;~:; ~..:;~;~;~ ~', ;:~][~-, .................................. C~mmissioner the commission Date
Form 10-403 Rev 12-1-85 Submit in triplicate
ARCO Oil and Gas Company
Well History - Initial Report- Daily
Instructions: Prepare and submit the "lllllilll Rel~ml" on the first Wednesday after a well is spudded or workover operations are started.
Daily work prior to Sl3udding should be summarized on the form giving inclusive dates only. :
District County. parish or borough
Alaska Lease North Slope Borough
Field or Unit
Kuparuk River ADL 25512
Auth. or W.O. no. T t e
AFE AK1622 Drill
JState Alaska
IWell no.
3Q-8
Doyon 9 API 50-029-21681
Operator IARCO W.I.
ARCO Alaska, Inc. 56.24%
Spudded or W.O. begUnspudded IDate 1/12/87 IH°ur 2000 hrs. IPri°rstatusifaW'O'
Date and depth Complete record for each day reported
as of 8:00 a.m.
1/13/87
1/14/87
16" @ 115'
1425', (1310'), Drlg
Wt. 9.2, PV 13, YP 21, PH 9.0, WL 12.8, Sol 6
Accept rig @ 1700 hrs, 1/12/87. NU diverter sys. Spud well
2000 hrs, 1/12/87. Drl & surv 12¼" hole to 1425'.
473', 0.7°, N52.6E, 472.99 TVD, -0.8 VS, 1.75, 2.30
854', 1.2°, N24.5E, 853.93 TVD, -1.04 VS, 6.65, 6.19
1223', 10.4°, N51.SW, 1221.27 TVD, 26.77 VS, 28.48, -12.25
1/15/87
16" @ 115'
4234', (2809'), Drlg
Wt. 9.3, PV 14, YP 16, PH 9.0, WL 10.4, Sol 7
Navi-Drl & surv to 4234'.
1412', 16.7°, N55.0W, 1404.92 TVD, 71.02 VS, 54.86N, 47.78W
1786', 28.2°, N53.0W, 1749.77 TVD, 214.14 VS, 139.5~N, 163.18W
2165', 39.5°, N53.3W, 2062.84 TVD, 426.56 VS, 270.11N, 330.81W
2721', 49.7°, N49.4W, 2451.19 TVD, 823.18 VS, 519.59N, 639.61W
3884', 51.8°, N43.5W, 3162.81TVD, 1737.68 VS, 1137.95N, 1391.84W
9-5/8" @ 4935'
4960', (726'), Bump plug
Wt. 9.7, PV 20, YP 16, PH 8.5, WL 10.6, Sol 10
Drl to 4960', wiper trip, C&C, POOH. RU & rn 124 jts, 9-5/8",
36#, J-55 BTC R-3 csg to 4935'. Cmt w/1200 sx AS IV cmt & 325
sx C1 "G". Displ using rig pmps, bump plug.
4261', 55.3°, N48.0W, 3386.76 TVD, 2037.99 VS, 1349.46N, 1536.97W
4860', 61.9°, N44.SW, 3697.08 TVD, 2546.22 VS, 1700.41N, 1909.62W
1/16/87
The a~b~is correct
see P .... %~a~ Se~tir~n 1~,~''~
Drilling, Pages 86 and 87.
9-5/8" @ 4935'
6690', (1730'), Drlg
Wt. 9.1, PV 7, YP 4, PH 10, WL 11.4, Sol 6
ND diverter. NU & tst BOPE. RIH, tst csg to 2000 psi. DO FC
& cmt to 4920'. Tst csg to 2000 psi. Drl cmt, FS & new hole
to 4970'. Conduct formation tst to 12.5 ppg EMW. Drl & surv
8½" hole to 6690'.
5339', 58.2°, N48.4W, 3936.18 TVD, 2958.05 VS, 1985.48N, 2211.07W
5845', 51.8°, N54.3W, 4226.26 TVD, 3371.83 VS, 2244.11N, 2534.47W
6221', 52.0°, N55.6W, 4458.26 TVD, 3667.63 VS, 2414.03N, 2776~69W
ITitle Drilling Supervisor
AR3B-459-1-D
Number all daily well history forms consecutively
as they are prepared for each well.
i Pag; no.
ARCO (.7~and Gas Company
Daily Well History-Final Report
Inalructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is avaiJable.
Accounting cost center code
State Alaska
District County or Parish
Alaska North Slope Borough
Field ILease or Unit
Kuparuk River I ADL 25512
Auth. or W.O. no. ITitle
AFE AK1622 J Drill
Doyon 9 API 50-029-21681
Operator A.R.Co. W.I.
ARCO Alaska, Inc. 56.24%
Spudded or W.O. begun Date
Spudded 1/12/87
[/[7/87
thru
1/19/87
1/20/87
Date and depth
as of 8:00 a,m.
Complete record for each day reported
TcOtal number of wells (active or inactive) on thisI
ost center prior to plugging
and I
labandonment of this well
IHour 2000 hrs. IPri°r status if a W'O'
7" @ 9367'
9400', (2710'), Displ'g cmt
Wt. 10.0, PV 21, YP 17, PH 9.5, WL 4.8, Sol 12
Drl & surv 8½" hole to 9400', short trip, C&C, POOH.
rn DIL/SFL/GR, FDC/CNL/CAL f/9400' to 4935', RD Schl.
wiper trip. RU & rn 216 jts, 7", 26#, J-55 BTC csg w/FS @
RU Schl,
Make
, FC @ 9281'. Cmt w/415 sx 50/50 C1 "G". Tail w/215 sx
G. Displ using rig pmps w/10.0 ppg brine. Bump plug.
,50.2°,N59.7W,4733.30 TVD,4007.55 VS,2596.38N,3064.58W
,50.2°,N60.6W,4975.26 TVD,4296.04 VS,2740.92N,3316.46W
,47.5°,N62.7W,5327.93 TVD,4695.58 VS,2932.55N,3671.61W
,47.4°,N65.7W,5647.79 TVD,5038.01VS,3084.46N,3985.29W
,46.9°,N67.8W,5988.51TVD,5395.62 VS,3229.17N,4322.74W
,44.5°,N71.8W,6263.66 TVD,5666.29 VS,3326.51N,4587.51W
,43.8°,N73.5W,6517.66 TVD,5899.31VS,3400.04N,4822.66W
9367'
Class
6659'
7037'
7573'
8046'
8547'
8941'
9295'
NU POPE, NU & tst tree
9367'
TD, 9281' PBTD, RR
7" @
9400'
10.0 ppg NaC1/NaBr
Fin cmt 7". CIP @ 0615 hrs. 1/19/87.
to 3000 psi. RR @ 1330 hrs, 1/19/87.
Old TO
Released rig
1330 hrs.
Classifications (oil, gas, etc.)
Oil
Producing method
Flowing
Potential test data
INew TD ] PB Depth
9400' TD 9281' PBTD
tDate 1/19/87 IKind Of rig Rotary
Type completion (single, dual, etc.)
Single
Official reservoir name(s)
Kuparuk Sands
Well no. Date Reservoir Producing Interval Oil or gasTest time Production
~ Oil on test Gas per day
P'u"mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date
corrected
The abo~j,~ correct
/[/O ~ ~), Drilling Supervisor
see Procedures Ma'l'fual, Section 10,
Drilling, Pages 86 and 87.
AR3B-459-3-C
Number all daily well history forms consecutively
as they are prepared for each well.
iPagano.
DivlNon of AtlantlcRIchfleldCompaf~y
ARCO Alaska, Ir{e, Alask
Post Office~b0~7~2~00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
Date: February 9, 1987
Transmittal #: 5912
RETURN TO:
ARCO Alaska, Inc.
Attn: Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
Ott Finals:
·
3Q-5 2" DIL 1-26-87 5060-10130
Cyberlook 1-26-87 9500-10100
2" FDC Raw 1-26-87 7844-10104
~.~ 2" FDC 1-26-87 7844-10104
Porosity
5" FDC Porosity 1-26-87 7844-10104
5" FDC Raw 1-26-87 7844-10104
5" DIL 1-26-87 5060-10130
3Q-8 5" FDC Raw 1-18-87 8740-9366'.
2" FDC Raw 1-18-87 '8740-9366
2" DIL 1-18-87 4940-9392
.......... ~ DIL 1-18-87 4940-9392
5" FDC Porosity 1-18-87 8740-9366
2" FDC Porosity 1-18-87 8740-9366
Cyberlook 1-18-87 8850-9300
Receipt Acknowledged:
DISTRIBUTION:
NSK Drilling
Vault (film)
Ai~ska,.,,, & ~-~ '."..' .... Gem
Anchorage
Rathmell D & M
L. Johnston (vendor pkg)
ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany
ARCO Alaska, In,
Post Offit
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
Date: February 9, 1987
Transmittal #: 5911
RETURN TO:
ARCO Alaska, Inc.
ACtn: Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
3Q-8' Open 'Hole LIS Tape + Listing 1-18-87 J~72168
Receipt Acknowledged:
DISTRIBUTIONf
D. Wetherell
ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRIchfieldCompany
December 29, 1986
Mr. J. B. Kewin
Regional Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
Anchorage, Alaska 99510-0360
Telecopy:
(907) 276-7542
Re: Kuparuk River Unit 3Q-8
ARCO Alaska, Inc.
Permit No. 86-193
Sur. Loc. 224!'FNL, 2207'FEL, Sec.17, T13N, R9E, LR~.
Btmhole Loc. 1431'FSL, 1901'FEL, Sec. 7, TI~N, R9E, UM.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
The permit to drill does not indemnify you from the probable need
to obtain additional permits required by law from other
governmental agencies prior to commencing operations at the well
site.
To aid us in scheduling field work, please notify this office 24
hours prior to commencing installation of the blowout prevention
equipment so that a representative of the Commission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. Where a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Co~nnnission may witness testing
before drilling below the shoe of the conductor pipe.
Although approved, Permit No. 86-193 is not valid, until the U.S.
Bureau of Land Management authorizes trespass of the well bOre
through tract USS 4275.
t ~i~r s ~ ./~-
C. V. Chafterton
Chairman of
Alaska Oil and Gas Conservation Commission
BY ORDER OF THE CO}~-~ISSION
dlf
Enclosure
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
?~r. Doug L. !,owery
Departme~t o2 Interior, Bureau of Land Management w/o encl.
l~r. Joe Dygas
-'- STATE OF ALASKA
ALASKA ~_.,_ AND GAS CONSERVATION C[,...MISSION
PERMIT TO DRILL
20 AAC 25.005
la. Typeofwork Drill ~¢,, Redrill ~l lb. Type of welI. Exploratory[] StratigraphicTest E3,, Development Oil ~
Re-Entry [] Deepen Service [] Developement Gas E~ Single ZonerS] Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
&R60 Alaska, Inc· RKB 60', PAD 23' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River 0i 1 Pool
P.O. Box 100360 Anchorage, AK 99510-0360 ADL 355024 ALK 3574
14. Location of well at surface 7. Unit or property Name 11. Type Bondlsee 2o
AAC 25.025)
2
241'FNL, 2207'FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit Statewide
At top of productive interval 8. Well nu ,tuber Number
1272'FSL, 1686'FEL, Sec.7, T13N, R9E, UM 3Q-8 #8088-26-27
At total depth 9. Approximate spud date Amount
1431'FSL, 1901'FEL~ Sec.7~ T13N~ RgE~ UN 01/04/87 $500~000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD)
property line 3Q-9 9539 'MD
1~,20' (~ Tnf_~l d~.n~hfeet ?~,' ~ .~,,rf~,-~. feet ";";~0 (~R~R'TV[1) feet
16. To be completed ¥or deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth900 feet Maximum hole angle52 o Maximum surface 221 4 psig At total depth(TVD) 32.23 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
2 .... I C"
-~ 82.5'~= ::-,,, ....... ,,~,d ,.,,,'~"' 35' 3,5' ~,15' 115 .... ~,~,,., cf
*~-, ~,.,,~-5/0,, i~,: n~ , ~ ~- ,.-,~, , io~, !~' 4806' 3740'
........................... I°'~0~., sx Arc Ill &
HF-ERW 325 sx C]:cc C b]e~d
R-1/2" 7" ?r-, ~q~t .I-Rc, RTl' cie;ftc,, '~/~' ~,4' qr_,'~q, R~Z,R' 900 SX C!ess
HF-ERW TOC c, if~ ' ,ahnv~ i-.nn nf K,,n~r~,~(
19. To be completed for Redrill, Re-entry, and Deepen Operations. '
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural
Conductor RECEIVED
Surface
Intermediate
Production i~'}]] ["; ~ ;?.
Liner Alaska 0it & Gas Cons. C0rnmissi0rl
Perforation depth: measured Anchorage
true vertical
20. Attachments Fili.n.g fee ~ Property plat [] BOP Sketch ~. Diverter Sketch ~ Drilling program f~
Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed repor~ [] 20 AAC 25.050 requirements
21. I hereby ce~-'~at the fore,~~s true and correct to the best of my knowledge
Signed Title Regional Drilling Engineer Date
' ~¢/ b~///'-'~ "' Commission Use Only ( HRE ) PD/025
I API number ] Appro~ date I See cover letter
Permit Nurr~'er ,~ ~ ~'~ 50-- ~ 'L.-;i--L-f L- ~ i /2 9 / 8 6 for other requirements
'C0nditions of approval Samples required [] Yes [~ No Mud log required ~ Yes ~ No
Hydrogen~su~lfi~e,measures [] Yes [] No Directional survey required ¢ Yes [] No
Require~l~,~'~essure for BOPE F12M; ~ 3M; [] 5M; [] 10M; I~ 15M
~.. ~, ~,~~_ by order of
Approved by -' Commissioner the commission Date
Form 10-401 Rev. 12-1-85
Submit in triplicate
ARDO ALASKA. ]~NO.
PAD JO. i/ELL NO, 8 PROPOSED
KUPA~UK FIELD.. NORTH SLOPE. ALASKA
· I
SCALE 1 IN.
R.RCLJ_E_C T.I_I3~ .... .-. ................
1000 FEET
i PAD 30,. WE1.L NO, 8 I~ROPOSED
' KUPARUK--FI !LB, NORTH}SLOPE, ALASKA . '
.
- ~ ~ ' :
'm ~, ~~, ............ ,~ ........ . . .
...... ~ ...................... ~ ..................................................... p ....... ~ ......... ~ .......
........... ~. ~JI. ~ -- ~~IF-- . ......................
.. ~ , , . ._~, ,
77., ~ :~ ...... . .................... - ....... ~ ........... ~ .....
........ ,. ,_ ,.., m
'T::] .... D]T-: -'-. :--~ - ,~ .... . ....................... ~ ..~:~:.:: :._'....
.......... ~-- -: ...... 4 .... :-- - t ......... ~ ....
................. ~ .............. ~ ........ ~ .... ~ ..... : :"-: 1 ........ ~ ....... :": f: :-:' ' ~ :- ~:-:-; ..... ::;: .
............. ........ ......
I'
, '-N ~4i- U~_ _ _____:~ -~IN. ~ " ~ ...... . ......
I
..... i .......... I
..... · ........... '
.......... l ....................... F ........ ~ .......... f ................ ~ ................. : ............ ~-.: ....
. ;: ~ ;/L'$2~S2]tZ]']Z~2~_~;]~;Z;L_L;;.~ ._ ~ ~ ........ I .......... I ......
...... :,~,, , ..... t ' ' t' ,,~'_,: ..... ',,'.,;, x ~ ~ ' ',''
I
............ ~ ......... = ........... : ................ ~ ...........
....... ~ .... '~ .... T~tT_'..':;:-;'2~ i, "::: :'-:-'~ ......... : S~;'.~_~7--- 2-~ ............ ' ........
· I
I00
I_
100
I
21oo
1 9qO
210C
220C
240C
250C
KUPARUK RIVER UNIT
20' DIVERTER SCHEMATIC
J L
DESCRIPTION
1. 16' CONDUCTOR
2. FMC SLIP-ON WELD STARTING HEAD
3. FHC DIVERTER ASSEHBLY WITH 1~O 2- I / 16"
2000 PS1 BALL VALVES
4. 20' 2000 PSI DRILLINg3 $POOL W/10' OUTLETS
5. 10' HCR BALL VALVES W/10' DIVERTER LINES,
A SINGLE VALVE 0~EN$ AUT01~ATICALLY UPON
CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE
REHOTELY CONTROLLEO TO ACHIEVE ~INO
DIVERSION.
6. 20" 2000 PSI ANNULAR I:q::tEVENTER
4
ARCO ALASKA, IN~., REOUESTS A~AL
OF THIS DIVERTER SYSTEM AS A VARIANCE
·
FROM 20AAC2S.0:55(b)
MAINTENANCE & OPERATION
2
i
.
.
UPON INITIAL INSTALLATION, CLOSE PREVENTER AND
VERIFY THAT VALVE OPENS PROPERLY.
CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH
DIVERTER LINES EVERY 12 HOURS.
CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN
INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED.
OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND
DIVERSION.
DO NOT SHUT IN WELL
UNDER ANY CIRCUHSTANCES
~G
I
11-3-86
7
6
DIAGRAM #1
15-5/~" 5000 PSI R~RRA BOP ~TAQ<
I. 16. - 20(~ PSI TAN<C~ START~ ~
3. I1' - ~ ~I X 1~8' - ~ ~I ~A~ ~
KI~ LI~
ACC~TOR C.J~PACITY TEST
I. C]-IE~ AI~ FILL ACO, MLATCR ~O:i:R TO PRCPER
LEVEL W/TH HYI:RNA. ZC FLUZD.
2. ~ THAT A(Z:t, MJ. ATCR ~ IS ~ PS! W2TH
~ TLII~ TI-~N (3.Cit~ ALL LIqITS $IM. LTN~E:~Y
4. RE~ C~ ~ ~o ~ ACCEPT~ L(~ER LIMIT
IS 45 ~(X~ Ct.08IN~ TD~ N~ I:~0 PSI REI~INII~
5
4
2
13-5/8" ~ STACK TEST.
DXE3EL.
2. CI-E:C~ THAT ALL LOI:X IX:Ill
FUtJ. Y RET~. ~F. AT
WITH ~NI3 JT .N~) ~ IN
LIllE VALVE3 ADJACENT TO ~ Sl'ACX. NJ. OTI. ER
4. PRESBLRE LP TO 250 I~I N~ 140.D FCR IOM/N. IN-
~ ~ TO 31:X:)O Pgl ~ 1.t3.D FCR 10 MEN.
L.II~E: VALVES. CLC]~ TCP PIPE RNI4B AI~ H(:R VALVES
~ KILL AI~ ~ LZI~E5.
6. TESTTO250~Z~~~Z~ INS'TEP4.
?. C:a~]:I~E: TESTIN6 ALL VN. VE3o L.I:I~E;~,
Wl"I"H A 250 I::~! LOW N~ ,3000 P~! HZOH. ~ AS IN
STEP 4. .
8. Q=I~ TOP PIPE: RN4B AFl3 CL0aE BOT"rCM PIPE.
TEST ~~ Pl~ ~ TO ~ ~I ~ ~ ~l.
9. ~~~ PI~ ~. ~ ~ ~~ ~
i0. ~~~ ~~ TOPAZ ~
~UID. ~ ~ V~ IN ~I~I~ ~ITI~
I~ ~ ~I~ V~, ~Y, ~Y ~, ~l~
PI~ ~ V~. ~ I~I~ TO ~I
~ ~I.
F~ SI~ ~ ~ TO ~I~I~ ~I~.
5100~4~'1 REV. -
MAY I S. 198.'
Density
DRILLING FLUID PROGRAM
Spud to Drill out
9-5/8" Surface Casing to Weight Up
9.6-9.8 8.7-9.2
Weight Up to TD
10.3
PV 15-30 5-15
9-13
YP 20-40 8-12
8-12
Viscosity 50-100 35-40
35-45
Initial Gel 5-15
2-4
3-5
10 Minute Gel 15-30
4-8
5-12
Filtrate APl 20
i0-20
9-10
9.5-10.5
9.5-10.5
% Solids 10± 4-7
9-12
Drilling Fluid S~stem:
- Triple Tandem Shale Shaker -
- 2 Mud Cleaners
- Centrifuge
- Desasser
- Pit Level Indicator (Visual & Audio Alarm)
- Trip Tank
- Fluid Flow Sensor
- Fluid Agitators
Notes:
Drilling fluid practices will be in accordance with the
appropriate regulations stated in 20 AAC 25.033.
Maximum anticipated surface pressure is calculated using a
surface casing leak-off of 13.5 ppg EMW (Kuparuk averase) and
a sas gradient of .11 psi/ft. This shows that formation
breakdown would occur before a surface pressure of 3000 psi
could be reached. Therefore, ARCO Alaska, Inc. will test our
BOP equipment to 3000 psi.
After 200' of departure, there are no well bores within 200'
of this proposed well.
In accordance with Area Injection Order No. 2, excess
non-hazardous fluids developed from well operations and those
fluids necessary to control the fluid level in reserve pits
will be pumped down the surface/production casing annulus.
The annulus will be left with a non-freezing fluid during any
extended shutdown in disposal opera~ions. The annulus will be
sealed with 175 sx of cemen~ followed by arctic pack upon
completion of the fluid disposal.
LWK5 / ih
GENERAL DRILLING PROCEDUR~
KUPARb~ RIVER FIELD
DEVELOPMENT WELLS
1. Move in rig.
2. Install Tankco diverter system.
3. Drill 12¼" hole to 9-5/8" surface casing point according to directional
plan.
4. Run and cement 9-5/8" casing.
5. Install and test blow out preventer. Test casing to 2000 psig.
6. Drill out cement and 10' new hole. Perform leakoff test.
7. Drill 8½" hole to logging point according to directional plan.
8. Run open hole logs.
9. Continue drilling 8½" hole to provide 100' between plug back total depth
and bottom of Kuparuk sands.
I0. Run and cement 7" casing. Pressure test to 3500 psig.
11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus.
12. Nipple down blow out preventer and install temporary Xmas tree.
13. Secure well and release rig.
14. Run cased hole logs.
15. Move in workover rig. Nipple up blow out preventer.
Pick up ?" casing scraper and tubing, trip in hole to plug back total
depth. Circulate hole with clean brine and trip out of hole standing
tubing back.
17. Perforate and run completion assembly, set and test packer.
18. Nipple down blow out preventer and install Xmas tree.
19. Change over to diesel.
20. Flow wmll to tanks. Shut in. '
21. Secure well and release rig. '
22. Fracture stimulate.
SHALE
SHAKERS
.~ ST
PIUD
CLEANER
R .,e.-~,, STIR _ ~, STIR
[~PiUO ii.! !ENTRIFU!E1
CLEANERI ' ' -
TYPICAL I"IUD SYSTEM SCHEMATIC
LWK4/ih
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
November 19, 1986
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT- Conductor As-Built Location Plat - 3Q Pad
(Wells 1-16)
Dear Mr. Chatterton.
Enclosed is an as-built location plat for the subject wells. If
you have any questions, please call me at 263-4944.
Sincerely,
d. ~ruber
Associate Engineer
JG/dmr
GRU1/44
Enclosure
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompeny
II I
17 16
, I0~ ~t' &t"
yJCINJTY W
SCALE ~ I" ' 2 MIL~
N..L WELLS LOCATED IN SEC. 17,
TI3N, RgE, UMIAT MERIDIAN.
lw.i ! 'Y' ASPs" 'x'
I 16,025,87:S. 23
2 16,025,867.50
3 J6,025,861.28
4 16,025,855.29
6 16'025'849'36
I 8,025,843.37
7 16,o25,837.44
8 16,025,631.43
9 ~6,025, 81
~0 16,02~, 507.25
'11 16,025, 801.~1
,2 16,o2s,
I$ 16,025, 78~.31
~ 16,oas, 783.47
15 16,025, 777.44
515, 959.92
SIS, 984.20
516,008.42
516,032
$16,056.99
§16,081.28
516,105.64
516, I~J .72
5,16,202.58
516,226.82
516,251.42
S 16,275. ~0
5 II, 291.
511, 323.80
S11,~4t. 20
$11,372
I HEREBY CERTIFY THAT I AM PROPERLY
REGISTERED AND LICENSED TO PRAC-
TICE I~NO SURVEYING IN THE
STATE OF ALASKA AND THAT THIS
PLAT REPRESENTS A LOCATION
SURVEY M&DE BY ME: OR UNDER
MY SUPERVISION, AND TI'M,T ALL
DIMENSIONS ANO OTHER DETAILS
ARE CORRECT AS OF 11/2/'86.
NOT'~'$: I. ALL e..O~MXM&TEI ~ A.$.R, ZONE 4. 2.ALL DIST, MI::E~I ~ ~
4.~R FIELD W LN.16, ~ ZI-~.
5. O. G. E~VATION~ FROM
~~S PER LHD i ~ '~.:.
i i
LATITUDE LONGITUDE
70e 28' 54.758" 149052' 10.512"
70° 28'54.701"
70° 28' 54.639"
70° 28' 54.510"
70° 28' 54.52 I"
7(34, 28' 54.462"
70° ~8' 54.4o3"
70° 28' 54.
TOe 28'54. 165"
7o° 28' 54. ~o5"
70' 26' 54.o44'
70° 28' 53
70e 26' 53.925"
7o° aa' 53.
7O° 28' 53.6O0"
70I 28' 53.749"
149o 5~' 09.798''
149° 52' 09.0e6"
149° 52'06. $7t"
~4~ 5Z'07.658"
144jo 52'0t.944"
~4~ ~.'0~. ~.0"
~4~52'05.$7B"
141152'O2.6~5"
~4~ 52'01. 942"
141' ~.' 00. 521"
14tl 51' 59.814
14~ 51' 59.017"
14~0 51'58. 588"
[ ~'' I
DIst. EN.L. ! Ollt,EE'L: [0'..
2199'
2205'
2211'
2217'
2225'
2 22~1'
223~'
2241'
2255'
22~'
2271'
2277'
2213'
22.9'
22N'
2301'
2377'
2304'
220o'
2255'
2231'
ZZOT'
2134'
2 I10'
2085'
20~'
2037'
2DIS'
1989'
1919'
17.1
17.1
17. I
17.2
17. Z
17.3
1'/'.3
17.4
17.5
17.3
17.5
17.5
17.5
17.5
17.5
21.7
21.7
ZI .l
21.0
224
2~.0
22.0
21.1
21 .g
21.1
21.1
. .vJ..."4 g
~ee®eeeee · *; ~eee®ee
D.S.$Q
WELL CONDUCTOR ASSUlLT
I I IIllt Il I I
OqeW BY, AJN CldK BY, JWT ....... ·
DATE, II/10/N NSK I. 317-d$
I I/
CHECK LIST FOR NEW W~.~. PERMITS
ITM~ APPROVE DATE
1. Is
(2) Loc
(2 thru 8)
(3) Admin
'(9 thru 13)
thru "22
28)
(6)
(29 thru 31)
Geology:
WWB~ %
Engineerin~:,.
l.~S ~ BEW
HaH
rev: 07/18/86
6.011
2. Is
3. Is
4. Is
5. Is
6. ~Is
7.
8.
Company ,
YES
the permit fee attached ..........................................
well to be located in a defined pool .............................
well located proper distance from property line ..................
,,
well located proper distance from other wells ..................
sufficient undedicated acreage available in this pool ......
well to be deviated and is wellbore plat included .. ,. !..
Is operator the only affected party .................................
Can permit be approved before fifteen-day wait ......................
Lease & Well No.
NO
.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
For
29.
30.
31.
32.
Does operator have a bond in force ..................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
Is the lease number appropriate ............................... · ......
Does the well have a unique name and number .....
Is conductor string provided ........................................
Will surface casing protect fresh water zones .......................
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ...
Will cement cover all known productive horizons .....................
Will all casing give adequate safety'in collapse, tension and burst..
Is this well to be kicked off from an existing wellbore .............
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
Is a diverter system required .......................................
Is the drilling fluid program schematic and list of equipment adequate
Are necessary diagrsms and descriptions of diverter and BOPE attached.
Does BOPE have sufficient pressure rating - Test to .. $ ~O o psig ..
Does the choke manifold comply w/AP1 RP-53 (May 84) ..................
Is the presence of H2S gas probable .................................
exploratory and Stratigraphic wells:
Are data presented on potential overpressure zones? .................
Are seismic analysis data presented on shallow gas zones ............
If an offshore loc., are survey results of seabed conditions presented
Additional requir~ts -
, ,
IN.LTIAL GEO. UNIT ON/OFF
POOL CLASS STATUS AREA NO. SHORE
,
Well History File
APPENDIX
Information of detailed nature that is not
'particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information, of this
nature is accumulated at the end of the file under APPENDIx.
No special 'effort has been made to chronologically
organize this category of information.
-,..
..
ECE VED
~---- S C HLUMB E RGE R----~
F'Ei--: !: 1987 ~.~s TAPE
VERIFICATION LISIlNG
~-~,!aska Oil & Gas Cons.
A~chu~¢g~
LVP OIO.H02 VERIFICATION LISTING PAGE
~* REEL HEADER~'"~
SERVICE NAME :EDIT
DATE :87/01/22
ORIGIN :
REEL NAME :149476
CONTINUATION ~ :01
PREVIOUS REEL :
COMMENTS :LIBRARY TAPE
¢~ TAPE HEADER ~*
SERVICE NAME :EDIT
DATE :87/01/22
ORIGIN :7216
TAPE NAME :
CONTINUATION ~ :01
PREVIOUS TAPE :
COMMENT'S :LIBRARY TAPE
**FILE HEADER
FILE NAME :EDIT' .001
SERVICE. NAME
VERSION e :
DATE :
MAXIMUM LENGTH : 1024
FILE TYPE :
PREVIOUS FILE :
INFORMATION RECORDS
MNEM CONTE~NTS
UNIT TYPE CATE SIZE CODE
CN : ARCO ALASKA~ INC. 000 0,00 O1B 065
WN : 3q-B 000 000 004 065
FN : KUPARUK 000 000 008 065
RANG: 9E 000 000 002 065
TOWN: 13N 000 000 004 065
SECT: 17 000 000 002 065
COUN: NORTH SLOPE 000 000 012 065
STAT: ALASKA 000 000 006 06~
CTRY: USA 000 000 003 065
MNEM CONTENTS:
UNIT TYPE CATE SIZE CODE
PRE:S:. E 000 000 001 065
~ COMMENTS ~
.~.,.~.~~.~.~.~.,.~.,.*o,.~-,-~.~.~-~ .... ,.~..~.,.~.,.~.~ .... ~*.,.~.~ .... , .... ~.~..,.~.~.~.~..~..,.~..~.~..,..~.~.,..-~
.VP OiO.H02 VERIFICATION LISTING PAGE 2
~ SCHLUMBERGER
¢ ALASKA COMPUTING CENTER
SOMPANY = ARCO ALASKA INC
~ELL = 3Q-8
FIELD = KUPARUK
:OUNTY = NORTH SLOPE BOROUGH
STATE = ALASKA
JOB NUMBER AT AKCC: 72168
RUN J! DATE LOGGED: 18-JAN-87
LOP: R~CK KRUWELL
CASING
TYPE FLUID
DENSITY
VISCOSITY
PH
FLUID LO.SS
MATRIX SANDSTDNE
= 9.625" @ 4940' - BIT SIZE = 8.5" TO 9400'
= LSND POLYMER
= 10.1 LB/G RM = 3°6 @ 70 DF
= 46 S RMF = 3.96 @ 70 DF
= 9.0 RMC = 2.95 @ 70 DF
= 4°8 ~C'3 RM AT BHT = 1.8 @ 147 DF
NOTE: DIL/FDC/CNL HAVE REPEAT SECTION MERGED TO LOG FILE DUE TO REPEAT BEING
LOGGED DEEPER
· ~ THIS DATA HAS NOT BEEN DEPTH SHIFTEO - OVERLAYS FIELD PRINTS ~~
LVP OIO.H02 VERIFICATION LISTING PAGE
SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE:
DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIL)
DATA AVAILABLE: 9392' TO 4940'
FORMATIOI~ DENSITY COMPENSATED LOG (FDN)
COMPENSATED NEUTRON LOG (FDN)
DATA AVAILABLE: 9366' TO 8732'
GAMMA RaY IN CASING CGR.CSG)~
DATA AYAILABLE: 4975' TO 991'
~ DATA FORMAT RECORD ~
ENTRY.BLOCKS
TYPE SiZE REPR CODE ENTRY
2 ! 66 0
4 t 66
8 4 73 60
9 4 6'5 .lin
16 1 66
0 1 66 0
DAT~UM SPECIFICATIDN BLOCKS
MNEM SERVICE SERVICE UNLIT AP1 API API AP1 FIiLE SIZE SPL REPR
PROCESS
~VP OlO.H02 VERIFICATION LISTING PAGE 4
ID ORDER # LOG TYPE CLASS MOD NO.
DEPT FT O0 000 O0 0 0
SFLU OIL griMM O0 220 01 0 0
ILO OIL OHMM O0 120 46 0 0
ILM OIL OHMM O0 120 44 0 0
SP OIL MV O0 010 01 0 0
3R OIL GAPI OO 310 O1 0 0
TENS OIL LB O0 635 21 0 0
ER FDN GAPI O0 310 01 0 0
CALI FDN IN O0 280 01 .0 0
RHOB FDN G/C3 O0 350 02 0 0
DRHO FDN G/C3 O0 356 01 0 0
NRAT FON O0 420 01 0 0
RNRA FDN O0 000 O0 0 0
NPHI FDN PU O0 890 O0 0 0
DPHI FDN PU O0 890 O0 0 0
NCNL FDN CPS O0 330 31 0 0
FCNL FDN CPS O0 330 30 0 0
TENS FDN LB O0 635 21 0 0
GE CSG GAPI O0 310 01 0 0
TENS CSG LB O0 635 21 0 0
~ DATA
DEPT 9421.5000 SFLU 2.7540 ILD
SP -49.6250 GR 104.6250 TENS
(ALI 4.4805 RH.OB 1.5.088 DRHO
RNRA 3.2402 NPHI 39,6484 DPHI
FCNL 616.0000 TENS 1185,00'00 GR
DEPT 9400.0000 SF:LU 2.7515 ILO
SP -46.1250 GR ' 104,6250 TENS
CALI 4.4805 RHDB 1. 5088 DRHD
RNRA 3.2402 NPHI. 39.6484 DPHI
FCNL 616.0000 TENS 3720.0000 GE
DEPT 9300.0000 SFLU 12.1427 ILO
SP -122.7500 GR 62.4063 TENS
(ALI 8.3750 RHOB 2.6465 DRHO
RNRA 2.8223 NPHI 28.9062 DPHI
FCNL 775.0000 TENS 5404.0000 GR
DEPT 9200.0000 SFLU' 1.905.0 ILO
SP -120.0000 GR 108.2500 TENS
(ALI 8.6641. RH08 2.52.I5 DRHD
RNRA 3.6992 NPHI 46.1426 DPHI
FCNL 526.0000 TENS 5412.0000 GR
DEPT 9.100.0000 SFLU 56o1012 ILO
SP -148.1250 GR 56.0313 'TENS
CALI 8-4688 RHOB 2.2930 ORHO
RNRA 2.9609 NPHI 31.6895 DPHI
FCNL 871.5000 TENS 5384.0000 GR
2.8518
1185.0000
-0°0454
69.1674
-999.2500
CODE
68
68
68
68
68
68
68
68
68
68
68
(OCTAL)
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
00000000000000
68 00000000000000
68 00000000000000
68 00000000000000
68 00000000000000
68 00000000000000
68 00000000000000
68 00000000000000
68' 00000000000000
ILM 2.5617
GR 104.6250
NRAT 3.0488
NCNL 1997.0000
TENS: -99'9'2500
2.8534 ILM
3720.0000 GR
-0.0454 NRAT
69.1674 NCNL
-999.2500 TENS
4,7087 ILM
5404.0000 GR
0.1235 NRAT
0,2230 NCNL
-999.2500 TENS
2,0074 ILM,
5412.0000 GR
0.0977 NRAT
7°7980 NCNL
-999.2500 TENS
47.2755 ILM
5384.0000 GR
0.0630 NRAT
21.6461 NCNL
-999.2500 TENS
2.5567
104.6250
3.0488
1997.0000
-999.2500
5.3093
62.4063
2.6582
2188.0000
-999.2500
2.1296
108.2500
3.6758
1946.0000
-999.2500
56.2673
56.0313
2.8496
2582.0000
-999.2500
LVP 010.H02 VERIFICATIDN LISTING PAGE 5
DEPT 9000.0000 SFLU
SP -124.5000 GR
CALl 9.3750 RHOB
RNRA 4.2305 NPHI
FCNL 426.5000 TENS
DEPT 8900.0000 SFLU
SP -124.5000 GR
CALI 8.9687 RHO8
RNRA 3.5137 NPHI
FCNL 532.5000 TENS
OEPT 8800.0000 SFLU
SP -128.0000 GR
CALI 8.8672 RH05
RNRA 3.7402 NPHI
FCNL 505.5000 TENS
DEPT 8700.0000 SFLU
SP -126.0000 GR
CALl -999.2500 RHOB
RNRA -999°2500 NPHI
FCNL -999.2500 TENS
DEPT 8600'0000 SFLU
SP -3.5.8750 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL ,-999.2500 TENS
DEPT 8500.0000 SFLU
SP -29.6250 GR
CALI -'999.2500 RHO!B
RNRA -999.2500 NPHI
FCNL -999-2500 TENS
DEPT $400'0000 SFLU
SP -28.5000 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL '999.2500 TENS
DEPT 8300.00.00. SFLU
SP -32.1250 GR
CALI -999.2500 R'HOB
RNRA -999.250:0 NPHI
FCN~L -999-2500 TENS
DEPT 8200.0000 SFLU,
SP -13-3750 GR
CALl -999.2500 RHO~
RNRA -999..2500 NPHI
FCNL -999.2500 TENS
2.2101
96.7500
2.3809
49.8047
5784.0000
4.5310
112.2500
2.5059
40.8203
5200.0000
4. 3006
172.1250
2.4512
40.5273
5252.0000
4.8265
1B9.O000
-ggg. 2500
-999.2500
-999 . 2500
3.6195
162.1250
-999. 2500
-999.2500
-999.2500
3' 86'03
104.0000
-999. 21500
-999.2500
,-999. 2500
4.2603
110. 3125
-999. 2500
-999. 2500
-999 · 2500
5- 7112
91. 2500
'-999.2500
-999.2500
-999.2500
1.7297
156.1250
-999. 2500
-999. 2500
-999. 2500
ILD
TENS
DRHO
DPMI
GR
TENS
DEMO
DPHI
GR
ILD
TENS
DRHO
DPHI
GR
ILO
TENS
DRHO
DPHI
GR
ILD
TENS
DRHO
D P H l
GR
ILD
TENS
DR'HO
DPHI
GR
ILO
TENS
DEMO
DP HI
GR
ILO
TENS
DRHO
DPHI
GR
TENS
DRHO
OPHI
GR
1.9445 ILM
5784.0000 GR
0.0444 NRAT
16.3199 NCNL
-999.2500 TENS
3.3257 ILM
5200.0000 GR
0.0566 NEAT
8.7449 NCNL
-999.2500 TENS
3.5009 ILM
5252.0000 GR
0.0537 NRAT
12.0590 NCNL
-999.2500 TENS
3.5128 ILM
5248.0000 GR
-999.2500 NEAT
-999.2500 NCNL
-999.2500 TENS
3.4273 ILM
5164.0000 GR
-999.250.0 NRAT
-999.2500 NCNL
-999.2500 TENS
3.5598 ILM
5004.0000 GR
-99.9.2500 NEAT
-999.2500 NCNL
-999.2500 TENS
4.3461 ILM
4940.0000 GR
-999:2500 NEAT
-999 2500 NCNL
-999.2500 TENS
5.1444 ILM
5152.0000 GR
-999.2500 NEAT
-ggg.2500 NCNL
-999.2500 TENS
2.1701 ILM
5044.0000 GR
-999.2500 NEAT
-999.25.00 NCNL
-999.2500 TENS
2.1175
96.7500
3.9336
1805.0000
-999.2500
3.3960
112.2500
3.4082
1872.0000
-999.2500
3..6359
172.1250
3.3848
1891.0000
-999.2500
3.7,170
-999.2500
-999.2500
-999.2500
-999.2500
3.4567
-999.2500
-999.2500
-999.2500
-999.2500
3-7509
-999.2500
-999.2500
-999.2500
-99.9'2500
4.3254
-999.2500
-999.2500
-999.2500
-999.2500
5.4569
-999.2500
-999.2500
,-999.2500
-999.2500
2.1.428
-999.2500
-999.2500
-999.2500
-999.2500
LVP 010.H02 VERIFICATION LISTING PAGE 6
DEPT 8100.0000 SFLU
SP 26.8750 GR
CALl -999.2500 EM05
RNRA -999.2500 NPMI
FCNL -999.2500 TENS
DEPT SFLU
SP GR
CALI RHOB
RNRA NPHI
FCNL TENS
DEPT SFLU
SP GR'
CALI RHOB
RNRA NPHI
FCNL TENS
DEPT SFLU
SP GR
CALI RHOB
RNRA NPHI
FCNL TENS
D_E, PT
SP
CALt
RNRA
FC NL
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CALI
RNRA
FC NL
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CALI
R'NRA
FCNL
8OO0.0OO0
80.3750
-999.2500
-999.2500
-999.2500
7900.0000
90.5000
-999.2500
-999.2500
-999.2500
7800.0000
114.2500
-999,2500
-999.2500
-999.2500
7700o0000
126.2500
-999,2500
-999,25:00
-999,2500
7600.0000
129.7500
-999.250:0
-999.2500
-999,2500
7500.0000
I27.7500
-999,2500
-999,2500
-999,2500
7400.0000
135.5000
-999.2500
-999,2500
-999.2500
7300.0000
137.7500
-999.25:00
-999.2500
-999.2500
SFLU
GR.
RHO5
NPHI
TENS
SFL'U
GR
RHOB
NPHI
TENS
SFLU
GR
RHOB
NPHI
TENS
SFLU
RHOB
NPHI
TENS
SFLiU
GR.
RHOB
NPHI
TENS
1,9111 ILD
118.0000 TENS
-999.2500 DRHD
-999.2500 DPHI
-999.2500 GR
2.7996 ILD
93.3125 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
4.0229 ILD
1[8.8125 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
2.8954 ILD
120.6875 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
2.0036 ILO
80.4375 TENS
-999.2500 DEMO
-999.2500 DPHI
-999.2500 GR
2.0709 ILO
110.7500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
3.0257 ILO
122.4375 TENS
-999.2500 DRHO
-999.2500 DPHi
-999,2500 GE
3.1835 ILO
110.4375 TENS
-999. 2500 DRHO
.,,999. 2500 DPHZ
-999'2500 GR
3.4628 iLD
99.0625 TENS
-999.2500 DRHO
-999.2500 DP'HI
-g99.2500
2.0360
5060.0000
-999.2500
-999.2500
-999.2500
2.6668
5168.0000
-999.2500
-999.2500
-999.2500
4.0025
4832.0000
-999.2500
-999.2500
-999.2500
2.8182
4832.0000
-999.2500
-999.2500
-999.2500
2'1883
4764.0000
-999.2500:
-999.2500
-999.2500
2'1543
4584.0000
~99'9.2500
-999.2500
-999.2500!
3.1836
4684.0000
-999.2500
-999.2500
-999.2500
3.42t2
4644.0000
-999-2500
-999.2500
-999,2500.
3'6146
4524.0000
-999.2500
-999.2500
-999.2500
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NEAT
NCNL
TENS
ILM
GR
NEAT
NCNL
TENS
ILM
GR
N R A T
NCNL
TENS
GR
NEAT
NCNL
TENS
ILM
GR
NEAT
NCNL
TENS
GR
NEAT
NCNL
TENS
ILM
GR
NEAT
,NCNL
TENS
2.0546
-999.2500
-999.2500
-999.2500
-999.2500
2.6495
-999.2500
-999.2500
-999.2500
-999.2500
4.0816
-999.2500
-999.2500
-999.2500
-999.2500
2.8188
-999.2500
-999.2500
-999.25'00
-999.2500
2.2063
-999.2500,
-999°2500
-999.2500
-999.2500
2'i878
-999.2500
-999,2500
-999,2500
-999.2500
3.2201
-999.2500
-999'2500
-999'2500
-999.2500
3.4178
-999.2500
-999 -2500
-999,2500
-999 o 2500
3°6849
-999,2500
-999,2500
-999,2500
.-999,2500
LVP OlO.H02 VERIFICATION LISTING PAGE 7
DEPT 7200.0000 SFLU
SP 139.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 7100.0000 SFLU
SP 144.2500 GR
CALI -999.2500 RHOB
RNRA -999,2500 NPHI
FCNL -999.2500 TENS
DEPT 7000.0000 SFLU
SP 144.0000 GR
CALl -999.2500 RMOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 6900.0000
SP 150.6250
CALI -999.2500
RNRA -999.2500
FCNL -999.2500
DEPT 6800'-0000
SP 149.6250
CALI -999.250!0
RNRA -999o2500
FCNL -999.2500
DEPT 6700.0000
SP 153.1250
CALI -999,2500
RNRA -999.2500
FCNL -999.2500
D:EPT 6600,0000
SP 151.1250
CALl -999.2500
RNRA -999.2500
FCNL -999.2500
DEPT 6500.0000
SP 151.6250
CALl -999.2500
RNRA -9:99.2500
FCNL -999.2500
DEPT 6400.0000
SP 150.6250
CALI -999.2500
RNRA -999.2500
FCNL -999.2500
SFLU
GR
RHoB
NPHI
TENS
SFLU
GR
RHOB
NPHI
TENS
sFLu
GR
RHOB
NPHI
TENS'
SFLU
GR
RHOB
NPMI
TENS
SFLU
GR
RHOB
NPHI
TENS
SFLu
GR
RHOB
NPHI
TENS
3,5672 ILO
99,3750 TENS
-999.,2500 DRHO
-999,2500 DPHI
-9'99.2500 GR
3.3080 ILD
99.0000 TENS
-999.2500 DRHD
-999.2.500 DPHI
-999.2500 GR
3.3322 ILD
108.1875 TENS
-999.2500 DRMO
-999.2500 DPHI
-999.2500 GR
3.0538 ILD
79.0000 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
2.6211 ILO
114.6875 TENS
'-999.2500 DRHO
-999.2500 DPMI
-999.2500 GR
2.7917 ILD
109.8750 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
2.9815 ILO
107.6875 TENS
-99'9. 2500 ORHO
-999.2500 DPHI
-999.2500 GR
2.9830 ILD
110.3125 TENS
-999.2500 DRHD
-999.2500 DPHI
-999.2500 GE
3.0569
101.7500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
3.7114 ILM
4464.0000 GR
-999.2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.3935 ILM
4384.0000 GR
-999.2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.6094 ILM
4320.0000 GR
-999.2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.6807
4084.0000 GR
-999.2500 NRAT
-999.2500 NCNL
-999.2500 TENS
2.9284 ILM
3990.0000 GR
-999.2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.0559 ILM
4070,0000 GR
-999,2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.2130 ILM
3900.0.000 GR
-999.2'500 NRAT
-999.2.500 NCNL
-999.25'00 TENS
3.2284 ILM
3884.0000 GR
-999.2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.3948 ILM
3624,0000 GR
-999,2500 NRAT
-999.2500 NCNL
-999.2500 TENS
3.7286
-999.2500
-999.2500
-999.2500
-999.2500
3.4555
-999.2500
-999.2500
-999.2500
-999.2500
3.6409
-999.2500
-999.2500
-999.2500
-999.2500
3.9418
-999,2500
-999.2500
-999.2500
-999-2500
2.9033
-999.2500
-999' 2500
-999. 2500
-999.2500
3'1124
-999.2500
-999°2500
-999.2500
-999..2500
3.2387
-999.2500
]~99-2500
99'2500
-999.2500
3.2016
-999.2500
-999.'2500
-999.2500
-999'2500
3.3073
-999,2500
-999.2500
-999,2500
-999.2500
.VP OlO.HO2 VERIFICATION LISTING PAGE 8
DEPT 6300.0000 SFLU
SP 153.3750 GR
CALl -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 6200.0000 SFLU
SP 158.6250 GR
CALI -999.2500 RHD8
£NRA -99.9.2500 NPHI
FCNL -999.2500 TENS
DEPT 6100.0000
SP 158.8750
CALI -999.2500
RNRA -999.2500
FCNL -999.2500
DEPT 6000.0000
SP 155.8750
CALI -999.2500
RNRA -999.2500
FCNL -999.2500
DEPT 5900,0000
SP 154-6250
CALi .-999.2500
RNRA -999.2500
FCNL -999.2500
DEPT 5800'0000
5P 157.1250
CALI -999.25.00.
RNRA -999-2500
FCNL -999.2500
DEPT
SP t56.1250
CALI -999.2500
RNRA -999-2500
FCNL -999.2500
DEPT 5600.0000
SP 160. 0000
CALI -999:250
RNRA -999: 250~'
FCNL -999. 2500
DEPT 5500.0000
SP 156.3750
CALI -999.2500
RNRA -999-25.00
FCNL -9'99.2500
SFLU
GR
RHOB
NPH!
TENS
SFLU
GR
RHOB
NPHI
TENS
SFLU
GR
RHOB
NPHI
TENS
SFLU
GR
NPHI
TENS
SFLU
GR
RMOB
NPHI
TENS
SFLU
GR
RHOB
NPHI
T E N S
SFLU
GR
RHOB
NPHI
TENS
2.7643 ILD
107.2500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
2.4795 ILO
80.1875 TENS
-999.2500 DRHO
-999.2500 OPHI
-999.2500 GR
2.7553
90.5625
-999.2500
-999.25.00
-999.2500
3.1346
87.4375
-999.2500
.999.2500
-999.2500
3.0[34
102.5000
999.25.00
-999.2500
-999.2500
3.I648
79.6250
-999-2500
-999,2500
e999o2500
.3.4407
102.9375
'999.2500
-999o2500
-999.25.00
2. 7198
93.3125
-999.25:00
-999.2500
-999.2500
3-0226
90.5625
'-999-250,0
-999.2500
-999.2500
ILO
TENS
DRHO
OPHI
GR
ILD
TENS
DRHO
DPHI
GR
ILO
TENS
DRMO
DPHI
GR
ILD
'TENS
DRHO
DPHI
GR
,ILO
TENS:
DRHO
OPflI
GR
ILD
TENS
RHO
PHI
ILO
T'ENS
ORHO
DPHI
GR
3.0044
3564.0000
-999.2500
-999.2500
-999.2500
2.8719
3680.0000
-999.2500
-999.2500
-999.2500
3.5539
3624.0000
-999.2500
-999.2500
-999.2500
3.6773
3494.0000
-999.2500
-999.2500
-999'2500
3-5107
3394'0000
-999.2500
-999.2500
-999,2500
3'5655
3430.0000
-999.2500
-999.250.0
-999.2500
3.709Z
3374.0000
'999-2500
-999,2500
'-999-2500
3-0304
3200.0000
-99~.2500
-99 .2500
-999.2500
3.5599
3104.0000
-999.2500
-999.2500
-999.2500
ILM
GR
NRAT
NCN.L
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
'TEN S
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
I LM
GR
NRAT
NCNL
TEN S
I L M:
NRAT
NCNt.
TENS
ILM
GR
N:RA'T
NCNL
TEN:S
2.9785
-999.2500
-999.2500
-999.2500
-999.2500
2.8639
-999.2500
-999.2500
-999.2500
-999.2500
3.4975
-999.2500
-999.2500
-999.2500
-999.2500
3. 5476
-999-25.00
- 999 00
-999°2500
3.4090
-999.2500
-999.2500
-999.2500
-999.2500
3' 5.288
'-999.2500
-999'~500
-999' 500
-999 . 2500
3'6371
-9:99. 2500
-999'2500
-999'2500
-'999'2500
2.9.987
-999.2500
-99'9.:2500
-999.2500
-99.9.2500
3.4167
-999.2500
-999,2500
-999.2500
-999,2500
LVP 010.H02 VERIFICATION LISTING PAGE 9
OEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CALl
RNRA
FCNL
DEPT
SP
CALt
RNRA
FCNL
DEPT'
SP
RNRA
FCNL
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CA:LI
RNRA
FCNL
DEPT
SP
CALI
RNRA
FCNL
5400.0000 SFLU
155.1250 GR
-999.2500 RHO8
-999.2500 NPHI
-999.2500 TENS
5300.0000 SFLU
t54.8750 GR
-999.2500 RHOB
-999.2500 NPHI
-999.2500 TENS
5200.0000 S. FLU
158.0000 GR
-999.2500 RHOE
-999.2500 NPMI
-999.2500 TENS
5100.0000 SFLU
155.2500 GR
-999'2500 RMOB
-999.2500 NPHI
-999o2500 TENS
5000'0000 SFLU
150. 1250 GR
-999'2500 RHOB
-999.2500 NPHI
-999.2500 TENS
4900'0000 SFLU
-999.2500 GR
-999.2500 RHOB
-999.2500 NPHI
-999.2500 TENS
14800.0000 SFLU
-999.2500 GR
-999.2500 RHDB
-999.2500 NPHI
-999.2500 TENS
4700.0000 SFLu
-.999.2500 GR
-999.2500 RHDB
-999-.2500 NPHI
-999-2500 TENS
i~600.0000 SFLU
-999.2500 GR,,.
-999,Z~00 RHO~
-999.2500 NPHI
-999.2500 TENS
3.4149
89.6875
-999.2500
-999.2500
-999.2500
2.9~00
97.1250
-999.2500
-999.2500
-999.2500
2.4558
84.0625
-999.2500
-999.2500
-999.2500
2.9562
93.8125
-999.2500
-999.2500
-999.2500
3.4t49
81.2500
-999.2500
-999.2500
-999.2500
-999'2500
-999-2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
.-999.2500
-999.2500
-999.2500
-999.2500
-9'99.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999-2500
ILD
TENS
DRHO
DPHI
GR
ILO
TENS
DRMD
DPHI
GR
IL O
TENS
DRHO
D PHI
GR
ILD
TENS
DEMO
OPHI.
GR
ILD
TENS
DRHO
DPHI
GR
ILO
TENS
DRHO
DPHi
GR
TENS
DRHO
DPHI
GR
IL D
TENS
DRHO
DPHI
GR
ILD
T~NS
DRHO
DPHI
GR
3.8641
3210.0000
-999.2500
-999.2500
-999.2500
3.4961
2780.0000
-999.2500
-999.2500
-999.2500
3.0756
2710.0000
-999.2500
-999.2500
-999.2500
3.5142
2634.0.000
-999.2500
-999.2500
.999.2500
"3.798t
2564.0000
-9919.2500
-999.2500
84'6250
-999.2500
-999.2500
-999-2500
-999-2500
54.09,38
-99!9.2500
-999.2500
-999.250:0
-999'2500
61.87'50
-999.2500
-999.2500
-999.2500
-999.2500
58.2813
--999.2500
-999.2500
-999.2500
-999.25:00
51.9375
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
N:CN :L
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
I LM
GR
NRAT
NCNL
TENS
iLM
GR
NRAT;
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
3.6976
-999.2500
-999.2500
-999.2500
-999.2500
3.4090
-999.2500
-999.2500
-999.2500
-999.2500
2.9626
-999.2500
-999.2500
-999.2500
-999.2500
3.3322
-999.2,500
-999.2500
-999'.2500
-999..2500
3.6471
-999.2500
-999.2500
-999.2500
2554.0000
-999.2500
-999.2500
-999-2500
-999. 2500
2604- 00;00
-999.25,00
-999.2500
-999.2500
-999.2500
26~0.0000
-999-2500
-999.2500
-999.250~0
-999oZ'500
2624.0000
-999.2500
-999.250!0
-999.250:0
-999.2500
2584.0000
LVP 010.H02 VERIFICATION LISTING PAGE 10
DEPT 4500.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 4400°0000 SPLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 4300°0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 6200.0000 SFLU
SP -999.2500 GR
C~LI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 6100.0000 SFLU'
SP -999.2500 GR
CALI -999.2500 EH05
RNRA -9.99.2500 NPH!
FCNL -999.2500 TENS'
OEPT 6000.0000 S~F:LU
SP -999.2500
CALI -999.2500 RHO8
RNRA -999-2500 NPHI
FCNL -999°2500 TENS
OEPT 3900.0000, SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999°2500 NPHI
FCNL -9'99-2500 TENS
DEPT 3BO0.'O000 SFL.U
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999-2500 NPHI
FCNL -999.2500 TENS
DEPT 3700'0000 sFLu
SP -999.2500 GR
CALI -999.2500 RHOE
RNRA -999.25:00 NPHI
FCNL -999.2500 TENS
-999.2500 ILD
-999.2500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
-999.2500
-999.2500
-999.2500
-999-2500
-999.2500
-999.2500
-999.2500
--999.2500
-999.2500
-999.2500
-999.2500
-9'99.2.500
-999.2500
-99 9.25 0 0
- 999. 2500
-999.2500
-999. 2500
-999.2500
-999.2500
-9 99.25 o o
-999.2500
-999.2500
-999.2500
-999'2500
'-999- 2500
-999. 2500
- 999. 2500
- g 99 .* 2500
-999-2500
-999. 2500
-g99.2500
-999. 2500
-999' 2500
- 999- 2500
- 999 - 2500
-999.2500
-999.25'00
-999-2500
-999. 2500
-999. 2500
ILD
TENS
DRHO
DPHI
GR
ILD
TENS
DRHO
DPHi
GR
ILO
TENS
DRHO
DPHI
GR
ILO'
TENS
DRHO
DPHI
GR
ILD
TENS
DR:HO
0 P H.I
ILD
TENS
DR.HO:
DPHI
ILD
TENS
D R HO
DPHI
GR
ILD
TENS
O R HO
DPHI
-999.2500
-999.2500
-999.2500
-999.2500
52.9687
-999.2500
-999.2500
-999.2500
-999.2500
60.3438
-999.2500
-999.2500
-999.2500
-999.2500
67.0000
-999.2500
-999.2500
-999.2500
-999.2500
61.3125
-999'2500
-999'2500
'-999.2500
-999.2500
59-2187
-999'2500
-999.2500
-999'2500
-999.2500
46.78:'1!3'
-999.2500
-999.2500
-999.2500
-999.2'500
59.7500
'-999.2500
-999-2500
-999.2500
-999..2500
31.2969
-999.2500
-999.2500
-999.2500
-999'2500
54-0313
ILM
GR
NRAT
NCNL
TENS
ILM'
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NEAT
NCNL
TENS
ILM
GR
NEAT
NCNL
TENS
GR
NRAT
NCNL
TENS
ILM
NRA T
NCNL
TENS
GE
NEAT
NCNL
TENS
t LM'
NRAT
NC, NL
TENS
-999.2500
-999.2500
-999.2500
-999.2500
2574.0000
-999.2500
-999.2500
-999.2500
-999.2500
2520.0000
-999.2500
-999.2500
-999.2500
-999.2500
2560.0000
-999.2500
-999.2500
-999.2500~
-999.2500
2524'000:0
'-999.2500
.,999.2500
-999.2500
-999.2500
2514o0000
-9.9!9.2500
-999.2500
-999.2500
-999.2500
2444'0000
-999.2500
-999.2500
-999.25.00
999,2500
2634,000:0
-999.2500
-999.2500
-999'2500~
-999'2500
2364.0000
-999.2500
-999.2500
-999-2500
-999,2500
2356.0000~
.VP 010.H02 VERIFICATION LISTING PAGE
DEPT 3600.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999,2500 TENS
DEPT SFLU
SP GR
CALl RHOB
RNRA NPH[
FCNL TENS
DEPT SFLU
SP GR
CALI RMOB
RNRA NPHI
FCNL TENS
OEPT SF'LU
SP GR
CALI RHOB
RNRA NPHI
FCNL TENS
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CA~L[
RNRA
FCNL
DEPT
SP
CALI
RNRA
FCNL
DEPT
SP
CALI
RNRA
FCNL
DEPT
S'P
CALI
RNRA
FCNL
3500.0000
-999,2500
-999,1500
-999,2500
-999,2500
3600,0000
-999.2500
-999.2500
-999.2500
-999,2500
3300.0000
-999.2500
-999.2500
-999.2500
-999.2500
3200.0000
-999.2500
-999,2500
-999,2500
-999.2S00
3100'0000
-999.2500
-999.2500
-999.2500
-999.2500
3000,0000
-999,2500
-999,2500
-999,2500
-:999-2500
2900.0000
-999.2500
-999oZS0.0
-999.2500
-999.2500
2800.0000
-999.2500
'-999.2500
-999'2500
-999.2500
SFLU
GR
RHOB
NPHI
TENS
SF~
GR
RHDB
NPHI
TENS'
SFLU
GR
RHO'B
NPHI
TENS
SFLU
GR
RH:OB
NPHI
TENS
SFLU
GR
RHOB
NPHI
TENS
-999.2500 ILD
-999.2500 TENS
-999.2500 DRHO
-999.2500 OPHI
-999,2500 GR
-999.2500 ILO
-999,2500 TENS
-999,2500 ORHO
-999,2500 OPHI
-999,2500 GR
-999,2500 ILD
-999,2500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
-999,2500 ILO
-999.2500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
-999.2500 ILD
-999,2500 TENS
-999,2500 DRHO
-999..2500 DPHI
-999,2500 GR
-999,2500 ILD
-999,2500 TfNS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
-999.2500 ILD
-999.2500 TENS
-999.2500 DRH'O
-999,2500 DPHI
,-999,2500 GR
-'999,2500 ILO
-999.2500 TENS
-999.2500 DR. HO
-999'2500 OPHI
-999.2500 GR
-999,2500 ILO
-999.2500 TfNS
-999,2500 DRHD
-999.2500 DPHI
-999.2500 GR
-999.2500 ILM
-999.2500 GR
-999.2500 NRAT
-999.2500 NCNL
22.6719 TENS
-999.2500 ILM
-999.2500 GR
-999.2500 NRAT
-999.2500 NCNL
44.8750 TENS
-999.2500 ILM
-999.2500 GR
-999.2500 NRAT
-999.2500 NCNL
42.2500 TENS
-999.2500 ILM
-999.2500 GR
-999.2500 NRAT
-999.2500 NCNL
39.7188 TENS
-999,2500
-999,2500 GR
-999.2500 NRAT
-999,2500 NCNL
50,9375 TENS
-99962500 ILM
-999,2,~00 GR
-999,Z500 NRAT
-999°2500 NCNL
31.984~ TENS
-999.2500 ILM
-999.25oo GR
-'999]2500 NRAT
'999 2500 NCNL
49o&063 TENS
-999'2500 ILM
-999,2500 GR
-999,2500 NRAT
-999'2500 NCNL
35.3125 TENS
-999.2500 ILM
-999.2500 GR
-999.2500 NRAT
-999.2500 NCNL
46.8125 TENS
-999,2500
-999.2500
-999.2500
-999,2500
2280.0000
-999,2500
-999,2500
-999.2500
-999.2500
2244.0000
-999,2500
-999,2500
-999.2500
-999,2500
2214.0000
-999.2500
-999.2500
-999.2500
-999.2500
Zl?O'O000
-999.2500
-999,2500
-999'25100'
-999.25,001
2090.0000
'999.2500
-999,2500
-999-2500
-999.2500
2124.0000
-999.2:500
999,2500
-999,2500
'999:'2500.
2035'0!000
-999-2500
-999,250:0
-999,2500
-999,2500
2025'0000
-999'2500
-999.2500
-999.2500
-999.2500
2035.0000
LVP OlO.HO2 VERIFICATION LISTING PAGE 12
DEPT 2700.0000 SFLU
SP -999.2500 SR
CALI -999.2500 RMDB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 2600.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 2500.0000 SFLU
SP -999.2500 GR
CALl -999.2500 RMOB
RNRA -999.2500 NPHI
FCNL -999. 2500 TENS
DE PT 2400.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RMOB
RNRA -999.2500 NPH!
FCNL -999.2500 TENS
O E P T 2 300.0000 S F L U
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999. 2500 TENS
OEPT 2200'0000 SFLU
SP -999.250.0 GR
C A L I - 999.2500 R H a B
RNRA -999- 2500 NPHI
FCNL -999'2500 TENS
DEPT 2100.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 2000-0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 N!PHI
FCNL -999.2500 TENS
DEPT 1900.0000, SFLU
SP -999.2500' GR
CALI -999.2500 RHOB
RNRA -999.2500 'NPHI
FCNL -999-250'0 TENS
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
.~-999.2500
-999.2500
-999.2500
-999.25.00
-999.2500
-999.2500
-999.25.00
~-999.2500
-999.2500
-999°2500
-999' 2500
-9!99. 2500
- 999.25 O0
-999.:2500
-999.2500
-999,2500
-999.2500
-999.Z500
-999.2500
-999.2500
-999.2500
-999.250:0
-999-2500
-999.2500
-999.2500
-999.2500
-999.2:500
'999.2500
-999.2500
-999°2500
ILD
TENS
DRHO
DPHI
GR
ILD
TENS
DRHO
DPHI
GR
ILD
TENS
DRHO
DPHI
GR
ILO
TENS
DRHO
DPHi
GR
ILO
TENS
DRHO
OPHI
GR
TENS
DRMD
DPHI
GR
TENS
DRHD
DPMI
GR
ILO
TENS
DRHO
DPMI
GR
TENS
DRHO
DPHI
-999.2500
-999.2500
-999.2500
-999.2500
50.9687
-999.2500
-999.2500
-999.2500
-999.2500
58.9062
-999.2500
-999.2500
-'999.2500
-999.2500
3.2. 9062
-999.2500
- 999.. 250.0
-99'9,2500
-999.2500
~3'5000
-999.2500
.99'9.25:00
-9'99.2500
-999.2500
37,'3'750
-999.2500
-999,2500
-999.2500
-999.2500
41-7813
-999.2500
-999.2500
-999.250]0
-999.2500
. 57-6875
-999.2500
.999°2500
-:999.2500
-999.2500
36.2813
-999'2500
-999.2500
-999.2500
-999.2500
36.3438
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
T E N S
ILM
GR
NRA T
NCN L
TENS
ILM
GR
NRAT
NCNL
TENS
I L M
GR
NRAT
NCNL
TENS
GR
NRA T
NCNL
TENS
ILM
GR
NRAT
NC N L
TENS
ILM
GR
NRAT
NCNL
TENS'
-999.2500
-999.2500
-999.2500
-999.2500
2040.0000
-999.2500
-999.2500
-999.2500
-999.2500
1985.0000
-999.2500
-999.2500
-999.2500
-999.2500
I875.0000
-999.2500
-999.2500
-999,2500
-999.2500'
1895.0000
-999.2500
-999.2500
-999.2500
-999.250.0
I870.0000
-999.2500'
-999.2500
-999'250:0
-999.2500
1810.0000
-999..2500
-999.2500
-999°2500
-999-2500
1825,0000
-999.Z500~
-999.2500
·-999.2500
-999-25100
1755.0000
-999,2500
·-9'99.2500
-999.2500
-999.2500
1720-0000
LVP OlO.HO2 VERIFICATION LISTING PAGE
DEPT 1800.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RH05
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 1700.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 1600.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 1500.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 1400.0000 SFLU
SP -999.2500 GR
CALI -999'250:0 RHO~
FCNL -999-Z~UU t:eNa
DEPT 1300.0000 SFLU
SP -999.2508 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -.999.2500 TENS
DEPT 1200.0000 :SFLU
SP -999-2500 GR
CALI -999°2500 RHOB
RNRA -999.250'0 NPHI
FCNL -999.2500 TENS
DEPT 1100.0000 SFLU
SP. -999.2500 GR
CALI -999.2500 .RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
DEPT 1000.0000 SFLU
SP -999.2500 GR
CALI -999.2500 RHOB
RNRA -999.2500 NPHI
FCNL -999.2500 TENS
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999..2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999-2500
-9'99.2500
-999.2500.
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.25:00
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-99.9.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
ILO
TENS
DRHO
DPHI
GR
ILO
TENS
DRHO
OPMI
GR
ILD
TENS
ORHO
OPHI
GR
ILO
TENS
DRHO
DPHI
GR
ILO.
T E'NS
DRHO
TENS
DRMO
DPHI
GR
ILO
TENS
DRHO
OPHI
GR
ILO
TENS
DRMO
OPHI.
GR
ILD
TENS
DRHO
DPHI
GR
-999.2500
-999.2500
-999.2500
-999.2500
60.1875
-999.2500
-999.2500
-999.2500
-999.2500
43.1875
-999.2500
-999.2500
-999.2500
-999.2500
22.6406
-999.2500
-999.2500
-999.2500
-999.2500
27.0000
-999.2500
-999.2500
-999.2500
250~,
-999.2500
-999.2500
-999.2500
-999.2500
26.9687
-999.2500
-999.2500
-999.2500
-999.2500
34:.4063
-999';2500
-999.25100
-999.2500
-999'.2500
33.4375
-999.2500
-999.2500
-999.2500
-999.2500
57.2813
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM
GR
NRAT
NCNL
TENS
ILM'
GR
NRA T
NCNL
TENS
~ LM
GE
NRAT
NCNL
ILM.
GR
NCNL
TENS
I LM
GR
NRA'T
NCNL
TENS
-999.2500
-999.2500
-999.2500
-999.2500
1705.0000
-999.2500
-999.2500
-999.2500
-999.2500
1665.0000
-999.2500
-999.2500
-999.2500
-999.2500
1600.0000
-999.2500
-999.2500
-999.2500
-999.2500
1545.0000
-999.2500
-999.2500
-999.2500
-999'2500
1,510.0000
-999.2'500
.999.2500
-999.,2500
'999.2500
1430,0000
-999.250:0
-999.2500
-999.2500
-999.25010
1,375.00;00
-:999.2500
.999.2S00
-999.,2500
-g99'2500
1310~;00'00
-999.2500
-999.2500
-999.'2500
t260.0000
LVP 010.H02 VERIFICATION LISTING PAGE
DEPT
SP
CALI
RNRA
FCNL
991.0000 SFLU
-999.2500 GR
-999.2500 RHOB
-999.2500 NPHI
-999.2500 TENS
-999.2500 ILO
-999.2500 TENS
-999.2500 DRHO
-999.2500 DPHI
-999.2500 GR
~* FILE TRAILER
FILE NAME :EDIT .001
SERVICE NAME
VERSION ~ :
DATE :
MAXIMUM LENGTH : 1024
FILE TYPE :
NEXT FILE NAME :
EOF ~~~
· * TAPE TRAILER
SERVICE NAME :EDIT
OATE :87/01/Z2
ORIGIN :7216
TAPE NAME
CONTINUATION # :O1
NEXT TAPE NAME :
COMMENTS :LIBRARY TAPE
*~ REEL TRAILER
SERVICE NAME :EDIT
DATE :87/01/22
ORIGIN :
REEL NAME :149476
CONTINUATION ~
NEXT' REEL NAME :
COMMENTS :LIBRARY. TAPE
~*~**~ EOF
-999.2500 ILM
-999.2500 GR
-999.2500 NRAT
-999.2500 NCNL
60.2813 TENS
-999.2500
-999.2500
-999.2500
-999.2500
1260.0000
