United States
Environmental
Protection
Agency
Office of Water Office of Solid Waste EPA
Regulations and and Emergency 530-SW-87-005
Standards (WH-552) Response
Washington, D.C. ^fJKM?8*011' D-c-
20460 2046°
&EPA
TECHNICAL REPORT: APPENDIX C
EXPLORATION, DEVELOPMENT, AND PRODUCTION
iH
CRUDE OIL AND NATURAL GAS
-------
APPENDIX C
SAMPLING REPORTS
VOLUME 2
-------
11
-------
TABLE OF CONTENTS - VOLUME 1
Page
INTRODUCTION 1
ALABAMA 5
Investigation of Separation and Filtration Enterprises
(SAFE), Incorporated, June 12 and 13, 1986, Mobile . . 7
ALASKA 41
Investigation of Standard Alaska Production Company's
Gathering Center 2 (GC2), August 1, 1986, Prudhoe Bay . 43
Investigation of Standard Alaska Production Company's
Drill Pad G, Well No. G-30, August 2, 1986, Prudhoe Bay 57
Investigation of ARCO Alaska, Inc.'s Drill Site 3N,
August 3, 1986, North Slope 73
Investigation of Marathon Oil Company's Trading Bay
Production Facility, August 7, 1986, Cook Inlet .... 107
Investigation of Union Oil Company's Kenai Gas Field
Production Site 41-7, August 8, 1986, Kenai 133
CALIFORNIA 183
Investigation of Sun Exploration and Production
Company's Oxnard Oil Handling Facility, July 14, 1986,
Oxnard 185
Investigation of Shell California Production, Inc.'s
Central Water Treating System, July 15, 1986, Ventura 203
Investigation of Shell California Production, Inc.'s
River Bottom Unit Gosnell Well No. 51, July 15, 1986,
Ventura 225
Investigation of McFarland Energy, Inc.'s Section 24
Production Facility Midway Sunset Oil Field, July 16,
1986, Kern County 247
Investigation of Shell California Production, Inc.'s
Gore C Lease Oil Well No. 50-3P Midway Sunset Oil
Field, July 16, 1986, Kern County 265
COLORADO 295
Investigation of E-Vap, Limited, July 11, 1986, Greeley 297
111
-------
TABLE OF CONTENTS - VOLUME 1 (Continued)
^9__
.... 313
KANSAS
Investigation of Cindy Van Dyke's Gentry Lease Well
No. 2A, July 1, 1986, Montgomery County -^
Investigation of American Energies Corporation's
Munsell F Well No. 1, July 7, 1986, Pendennis 333
Investigation of DaMar Resources, Incorporated's 9067
Randa Well No. 1, July T, 1986, Hays 351
Investigation of Ritchie Exploration, Inc. and Cross
Wind Petroleum, Inc.'s Keith Garrett Well No. 1,
July 8, 1986, Wakeeney 365
Investigation of Oil Producers, Inc. of Kansas' Ott
Well No. 2, July 9, 1986, Wakeeney . 381
KENTUCKY 411
Investigation of Maverick Production, Inc.'s Glassco
Lease Well No. 1, August 21, 1986, Henderson County . . 413
Investigation of Ecus Corporation's Gamblin Lease
Production Facility, August 22, 1986, Hopkins County . 435
LOUISIANA ..... 453
Investigation of FMP Operating Company's S/L 195 No. 2
Oil Well, June 14, 1986, Plaquemines Parish ...... 455
Investigation of Sun Exploration and Production
Company's Sweetbay and Bateman Lake Tank Battery No. 2,
June 16, 1986, St. Mary Parish 493
Investigation of Mobil Oil's Bayou Blue Production
Facility, Jun 17, 1986, Iberville Parish 517
Investigation of Westland Oil Development Corporation's
Joseph Earl Bajoie No. 1 Oil Well, June 17, 1986,
Pointe Coupee Parish 535
MICHIGAN
557
Investigation of Wolverine Gas and Oil Company, Inc.'s
Hanover 7 Central Production Facility, July 29, 1986
Jackson County ^ ^
Investigation of Sun Exploration and Production
Company s Cameron Lease Well No. 1-10, July 30, 1986,
Gladwin County
IV
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TABLE OF CONTENTS - VOLUME 1 (Continued)
Page
Investigation of Powell Production, Inc.'s Savarino and
Stoll Well No. 6-21, July 31, 1986, Hillsdale County . 619
TABLE OF CONTENTS - VOLUME 2
NEW MEXICO 637
Investigation of Basin Disposal, Inc., Jun 25, 1986,
Bloorafield 639
Investigation of Amoco Production Company's USG
Section 18 Well No. 43, Jun 26, 1986, San Juan County . 715
Investigation of Cities Service Oil and Gas Corpora-
tion's State E Lease, June 27, 1986, Lea County .... 745
OKLAHOMA 761
Investigation of Ward Petroleum Corporation's Rowe
Lease Well No. 1-20, June 26, 1986, Grady County . . . 763
Investigation of George Kahn Operating Company's Mary
Allen Tank Battery, Jun 27, 1986, Oil Center 793
Investigation of Royce Kelly's Centralized Disposal
Pit, June 29, 1986, McClain County 809
PENNSYLVANIA 827
Investigation of Franklin Brine Treatment Corporation,
September 3, 1986, Franklin 829
Investigation of Mark Resources Corporation's Hazlett
Well No. 1, September 4, 1986, Venango County 855
TEXAS 867
Investigation of Exxon Company, USA's Hawkins Field
Unit Well No. 1210, June 19, 1986, Wood County .... 869
Investigation of Mobil's C. W. Belcher Lease Production
Facility, Jun 20, 1986, Talco 886
Investigation of Murexco Petroleum, Inc.'s Frye Lease
Oil Well No. 1-29, June 23, 1986, Wheeler County . . . 925
Investigation of Chevron USA, Inc.'s W. V. Lister No. 1
Gas Well Production Facility, June 24, 1986, Wheeler
County 999
v
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TABLE OF CONTENTS - VOLUME 2 (Continued)
Page
UTAH 1015
Investigation of Meridian Oil Company's Navajo-Federal
Well No. 23-4, June 29, 1986, San Juan County 1017
Investigation of Marathon Oil Company's Tin Cup Mesa
Well No. 1-25, Jun 30, 1986, San Juan County 1031
Investigation of Wexpro Company's Island Unit No. 27,
July 2, 1986, Uintah County 1077
WEST VIRGINIA 1099
Investigation of Scott Oil Company's Garvin Lease Well
No. S-614, August 19, 1986, Jane Lew 1101
WYOMING 1123
Investigation of Diamond Shamrock Exploration Company's
Myers State Well No. 41-16, July 13, 1986, Gillette . . 1125
Investigation of Amoco Production Company's LACT No. 4,
July 14, 1986, Midwest 1147
Investigation of Waste, Incorporated1s Lawrence Brown
Disposal Lagoon, July 15, 1986, Uinta County 1173
Investigation of Sun Exploration and Production
Company's Luckey Ditch Fed B Well No. 4, July 16, 1986,
Uinta County 1189
vi
-------
NEW MEXICO
C-637
-------
C-638
-------
Sampling Report
Investigation of Basin Disposal Inc.
Bloomfield, New Mexico
June 25, 1986
SITE INFORMATION
Site Selection
EPA specifically selected the Basin Disposal facility to obtain
technical information and analytical data regarding the regional
practice of using centralized pits for disposal of wastes from
multiple oil and/or gas sources. More detailed information about
the rationale for selection of centralized disposal pits is
contained in Appendix B of the EPA Technical Report (EPA 530-
SW-87-005).
EPA worked cooperatively with the New Mexico Oil Conservation
Division to identify and select the Basin Disposal facility. No
problems were encountered arranging for sampling to be conducted
on June 25, 1986.
Site Location
Basin Disposal Inc. is located 3 miles north of Bloomfield, NM on
the west side of NM Highway 44. Figure 1 is a map indicating the
disposal site.
The site is operated by Basin Disposal Incorporated, whose
mailing address and telephone number are:
PO Box 100
Aztec, NM 87410
505-334-3013
Contact Name: Sally Sandel
Attendees
Sampling of Basin Disposal Inc. was performed by CENTEC
Corporation personnel on June 25, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
Andy Procko, Engineering
Manager, Acting Technician
EPA Representative: Susan de Nagy, Office of Water,
Project Officer
State Representative: Dave Boyer, Environmental
Bureau Chief, NM Oil
Conservation Division
C-639
-------
M71°°0"N
«70
SITE LOCATION
0 . 1L. X.
-.-'^-^ '^W/-^;--^-.^*^ ";" •- '. ::-
-« . 9° - J M«? • ••" --7 .W ».- _!-' >--r- ~--^-«
i! - d A f kJ ? -:.. -' -*:* V'"" "ft":-- ' -^--- ^-'
i L '\i i ^r^!f j
) s *^£ OX C,OU
r-.S ^-?7 ,"K*J) '/*.-- r
(r •>, C,,OLA>/ --<-i/--.
•f ::"->-ia:<;&
: .'.23 : i —--24 - .A..-;--- "19 - L
.--f~-- .°'-i-A~; > ^r~" 1
'•'-•* ' =
:"?; r"'27..'': . -[-
jv-- f. J^T__-'':
.^fe^.;
> ...';-••»•'-— 4-^y*^i—T -••-.Tf-^'r? •--*•'..).- •
.,,,:.-: . c-;^-' '—T" ^•^•'" -'^^X^ = ^'
• "^jf-* v* * *. r""
Figure 1. Location of Basin Disposal Inc., Bloomfield
New Mexico
C-640
-------
Operator Representatives: A. R. Bryan
David Turner, Company Part-
Own er
American Petroleum
Institute Representative: Bill Freeman, Observer
Site Description
Basin Disposal Inc. is located in the San Juan Basin in rural
mesa; the depth to groundwater is over 250 feet and the nearest
surface water is over 2 miles away. There are no drinking water
wells within a 1-mile radius of the site. The soil in this area
is sandy clay. The climate at this site is net evaporation.
This site is a commercial central pit facility for mud and brine.
Annual operation hours are 4056. Proximity of clientele ranges
within a 50-100 mile radius from the facility. The facility
charges $50 per load for produced water and $75 per load for
drilling mud. A load is approximately 80 bbl. The facility
sells approximately 200 bbl reclaimed oil per month.
Figure 2 is a schematic diagram of the disposal site. Three
separate pits were constructed for the site: two drilling mud
pits and one brine pit. Each mud pit measured 150 feet by 70
feet. The brine pit measured 285 feet by 185 feet. All pits
were constructed above grade. The mud pits were unlined. The
brine pit had a double plastic liner with thickness of 20 ml and
40 ml. There was a sand layer between the liners. Leak
detection monitoring was required. There was a source to catch
leachate if the first liner leaks. The brine pit had a sprinkler
system to enhance fluid evaporation. The pits are filled every
day as material is trucked in from outside locations. On the day
of sampling, the depth of the brine pit was 13-15 feet, and the
depths of the mud pits were 4-6 feet. The pits were fenced. The
total site construction costs were $450,000. Monthly operational
costs at this facility include full-time salary for one employee
and electricity costs for the trailer unit and the pumps for the
heated separation unit.
Additional information is available in the following Attachments:
Attachment C: Design and Engineering Reports, Basin Disposal
Inc.
Attachment D: Evaporation Pit Geological Report
Attachment E: Bill of Lading Used by Basin Disposal Inc.
Permits
A copy of the facility permit was not available at the time of
sampling.
C-641
-------
n
K)
MOP PIT
O
QQQ
HEATED
S(Mt\TLtD
PIT
\50'
TAMS
-------
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The sample collected at Basin Disposal Inc. consisted of one
supernatant sample from the brine pit. Figure 3 shows the
sampling locations within the brine pit. Sample points were
accessed by boat. Thus, there was no discrepancy between the
actual and measured sample points caused by the inaccessibility
of the measured point.
Sampling Methods and Equipment
To collect samples, the brine pit was measured in order to
identify four quadrants and locate the center of each quadrant.
Sampling was conducted with the liquid thief from the boat.
Photos 1-3 (Attachment A) show the sample collection from the
brine pit. At the direction of the EPA Project Officer, a sludge
sample from the brine pit was cancelled since there was concern
that the liner might be punctured by the sludge sampling
equipment. Neither of the drilling waste pits was sampled.
The pit supernatant was tested onsite for pH after the completion
of sampling. The results of the test gave the water a pH of 8.
Due to time constraints, the samples were held in refrigeration
overnight before shipment to the laboratories.
C-643
-------
T
i
I
O
i
O
— o
O 4
O-
Figure 3
PO\MT
Sampling Locations in Basin Disposal Brine Pit
C-644
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-645
-------
C-646
-------
Photo 1. Sample collection from brine pit
O
I
Photo 2. Sample collection from brine pit
-------
C-648
-------
ATTACHMENT B: PERMITS
C-649
-------
C-650
-------
No permit specific to the operation
of this site is available.
C-651
-------
C-652
-------
ATTACHMENT C:
DESIGN AND ENGINEERING REPORTS,
BASIN DISPOSAL, INC.
C-653
-------
C-654
-------
ENGINEERING & PRODUCTION CORP.
Petroieum Engineering Consulting
Lease Management
Contract Pumping
3001
PO Qrwei-419
Farrwxjiax Nev» Wexco 374C1
[5051327-4892
BASIN DISPOSAL, INC.
PROPOSED
PRODUCED WATER
EVAPORATION PIT
SAN JUAN COUNTY, NEW MEXICO
August 14, 1985
OIL CONSERVATION DIVISION
A:,G 15 1S35
RECEIVED.
Ewell N
State of
Walsh, P.E.
New Mexico
Registration No. 4324
C-655
-------
PAGE NO
P re r ace
Location
Desisn and Constructior
Materials
Leak Detection System
Installation of Flexibl
Skinnier Tanks
Fence and Sign
Ma i nt enan ce
Contingency Plan
CALCULATIONS
Pit Level
Wave Calculations
Non-Breaking Wave Force and Moments
Berm and Levee Calculations
4
4
5
1 thru 3
4
5 & 6
7 & 8
C-656
-------
FIGURES
Plat of Acreage for disposal pit with
topography, outline of pit area and
profile lines (Pocket Back of Report)
North-South Profile A-A'
North-South Profile B-B'
North-South Profile C-C'
North-South Profile D-D'
West-East Profile V-V'
West-East Profile W-W
West-East Profile X-X'
West-East Profile Y-Y'
Slope Protection and Liner Anchor
Vents
Leak Detection System
Pond Inlet and Leak Detection
System Installation.
Leak Detection System - Thru Brem and Sump
Skimmer Tanks
FIGURE NO
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
C-657
-------
PREFACE
The purpose of the disposal pit is to provide a means
of oil and gas producers to dispose of produced water in an
approved disposal pit. The disposal pit will also be made
available to industries or persons that have to dispose of
water .
C-658
-------
-2-
LOCATION
It is proposed to construct a disposal water pit in an
area of Units E and F, Section 3-T29N-R11W, San Juan County,
X e v Mexico.
The area is located adjacent to State Highway 44 approx-
imately three miles north of Bloomfield, New Mexico.
DESIGN AND CONSTRUCTION
1. Anticipated Disposal Volume:
The estimated amount of water that will be made avail-
able is unknown. However, it is proposed to install a spray
evaporative system, if necessary, to increase the amount of
evaporation of the water to prevent the pit from becoming
to full' for normal and safe operations. The water volumes
anticipated are as indicated in calculations.
2. Pit will be of rectangular configuration, (Figure No. 1), and
berm or levees constructed as indicated in Figures No. 2
through Figure No. 9.
3. Freeboard allowance will be 2.5 feet. Maximum water elevation
5719.5 feet with berm or levee elevation 5722 feet. Wave
action was calculated to have a crest of elevation 5720.02
feet and a trough of elevation 5719.22 feet. See calculations.
4. The berm or levees will be constructed with an inside slope
of 3:1 and outside slope of 3:1.
5. Top of levee is to be 12 feet wide.
6. "The pit will incorporate a double liner system with leak
detection system installed between primary (top) and secondary
(bottom) liner. See Figures No. 12 through 14.
C-659
-------
-3-
MATERIALS
It is proposed to utilize a flexible membrane for the
primary and secondary liners.
Primary Liner:
Shelter-Rite XR5 8130 geomembrane . Resistant to
deterioration from exposure to sunlight and also re-
sistant to hydrocarbons. Thickness - 36 mils.
Secondary Liner:
Polyvinyl Chloride (PVC) geomeinbrane. Thickness
20 mils.
LEAK DETECTION SYSTEM
The leak detection system will be a drainage and sump
system. See Figures No. 12 through 14.
INSTALLATION OF FLEXIBLE MEMBRANE LINERS
1. The Aztec, New Mexico OCD District Office will be notified
a minimum of 24 hours in advance of installation of second-
ary line.
2. Pit liner will be installed and joints sealed according to
manufacturers specifications and with approval of Division
representative.
3. Liner will install on top of berm or levee as indicated in
Figure No. 10 .
4. Vents, 16 to 20, will be installed for venting of air or gas
that may accumulate beneath liner Geote^tile padding (Grade
200, thickness - 60 mils) will be put on slopes, between
liners. See Figure No. 11.
C-660
-------
-4-
SKIMMER TANKS
Two 400 barrel skimmer tanks will be installed on West
end of pond. See Figure No. 15 for skimmer tank design.
The tanks will be installed above ground with elevation
sufficient to allow gravity flow of water into the pond.
The tanks, and also the slop* oil tank, will have berms
around tanks to contain spill or leakage of tank.
FENCE AND SIGN
1. A fence will be contructed around all facilities, outside
of berm or levee area, to prevent livestock from entering
the facility area.
2. A sign, 12" x 24", will be installed at the facility for
identification as to Operator and legal locations.
MAINTENANCE
1. Leak detection sump will be inspected at least once a week,
2. The outside walls of the levee will be maintained in such
a manner to prevent erosion and will be inspected after
heavy rainfall.
C-661
-------
-5-
CONTINGENCY PLAN
1. If fluid is found in detection sump a sample will be obtain!
and analyzed to determine if the fluid is the same fluid
that is in the disposal pit.
2. If fluid is determined to be the same as in the disposal pit
a. No additional water will be put in disposal
pit.
b. The spray evaporative system will be utilized
to evaporate water as fast as possible.
c. If spray evaporative system is not removing fluid
at a sufficient rate, frac water storage tanks
will be utilized as storage for removal of water
from pit.
d. When water has been removed the pit and liner will
be inspected and any repairs will be made as per
liner manufacturer recommendations.
C-662
-------
COMPANY: BASIN DISPOSAL, INC.
LOCATION: UNIT: E ?< F SECTION:
COUNTY: SAN JUAN
WELL NAME:NONE
DATE 06-13-35
3 TOWNSHIP: 29N
STATE: NEW MEXICO
BASDISP
Al..1336
A337.. N44
RANGE:
1 1W
SIZE: DEPTH-FT:TOT. - 13.
MID-POINT-FEET: WIDTH-
AREA:
CUT- 7 TO 12 BERM- 3 TO 11
136 LENGTH- 307 FETCH-
41752 FT---2
VOLUME: AVERAGE FLUID HT.
DISPOSAL RATE,Bbls/D
ANNUAL 750.00 " ' START MONTH NO.-
10.5 FT. :• FT-"-3- 433396
Bbls-
10
7807.
<>::
0 v
Of
0 ;
t~\i
-------
n-i
MONTH
CUM.
JAN
FEB
MAR
APK
MAY
JUN
JUL
AUG
EEF'
GCT
MOV
DEC
DAYS/MO
31
29
31
30
31
30
31
31
30
31
30
31
FRECIP-
IT AT T <~IM
I H 1 i UlN
IN/MO
0.52
0.55
0.61
0.58
0.46
0. 40
0.91
1.O1
0.96
0 . 99
O.45
0 . 63
LAKE "
C"l t AC*
tVHi •
IN/MO
0.96
1.56
3.79
6.34
8.01
8.83
8.73
7.38
5.71
3.79
2.03
0.99
DISPOSAL
WATER
BBLS/DA
750.00
75O.OO
750. OO
750.00
750.00
750 . 00
75O.OO
750.00
750.00
750.00
750.00
75O.OO
DEPTH
FEET
3.09
2.74
2.86
2.55
2.50
"^ T *-»
.•I. • -j-i
2.48
2.6O
2.63
2.8?
2.89
3. 10
CUM.
DEPTH
FEET
4.76
7.85
10.59
—
—
—
—
—
—
—
—
—
•™
SPRAY E
LOSS C
FEET
0 . 00
0 . 00
-2.86
—5 . 53
-5.72
-8.30
-8. 58
-8.58
-5.53
-8.58
-1.38
-1.43
:VAP.
:UM.DP]
FEET
4,1
7,!
10,!
10,i
7,i
4.:
O.i
0.'
0,
0.
0,
1.
3.
TCTAL
365
8.07
8.12
NOTE: Commence spray evaporation February or March
YEAR
MCNTH
CUM.
JAN
FEB
MAR
APR
MAY
JUN
JUL
AUG
SEP
OCT
MOV
DEC
TOTAL
PAGE NO.
DAVE/MO
31
28
31
3O
31
30
31
31
30
31
30
31
365
2 OF 8
PRECIP-
ITATION
IN/MO
0.52
O. 55
0.61
0.58
O.46
0 . 40
O.91
1.01
O.96
0.99
0.45
0 . 63
8.07
LAKE DISPOSAL
EVAP. WATER
IN/MO BBLS/DA
0.96
1.56
3.79
6.34
SoOl
8.83
8.73
7.38
5.71
3.79
2.03
0.99
58. 12
750.00
75O.OO
750.00
750.00
750.00
750.00
75O.OO
75O.OO
750.00
750.00
750.00
750.00
CUM.
DEPTH DEPTH
FEET FEET
_
3.09
2.74
2.86
2. 55 —
2.50
2.32
2.43
2.60
2.63
2.89
2.89
3. 10
SPRAY EVAP.
LOSS CUM.DI
FEET FEE
-1.43
-2=58
-2.86
-5.53
-5.72
-8.30
-8.58
-8.58
—5 . 53
-8.53
-1'. 38
-1.43
3
4
5
5
2
0
0
C
C
c
C
]
"
C-664
-------
YEAR
4
MONTH
CUM.
JAN
FEE
MAR
APR
MftV
JUN
JUL
ALJG
SEP
CCT
NQV
DEC
DAY3/MO
31
28
31
3O
31
30
31
31
30
31
30
31
PRECIP-
ITATION
IN/MO
O.52
0.55
0.61
0.58
0.46
O.40
0.91
1.01
O.96
0.99
0.45
O. 63
LAKE :
EVAF -
IN/MO
0.96
1.56
3.79
6.34
8.01
8.83
8.73
7.33
5.71
3.79
2.03
0.99
DISPOSAL
1 l/\ T ^d
WATER
BBLS/DA
750.00
750.00
75O.OO
750.00
750.00
750.00
750 . OO
75O.OO
750.00
75O.OO
750.00
750.00
CUM.
T\CC>T~L-1 ^ C C* T i t
DEPTH DEPTH
FEET FEET
_
3 . 09
2.74
2.86
2.55
2.50
2.32
2.48
2 . 60
2.63
2.89
2.89
3.10
SPRAY E
t noc r
LQoS I
FEET
-1.43
-2.58
-2.86
— 5 . 53
-5.72
-8.30
-8.58
-8.58
—5. 53
-8.58
-1.38
-1.43
[VAP.
•M IM nPTW
-Un . Ui i n
FEET
3. 18
4.S4
5.00
5.00
2.O1
O.OO
O.OO
0.00
O.OO
0 . OO
0.00
1.51
3. IS
-QTAL
3.07
58. 12
YEAR
5
MONTH
CUM.
JAN
FEB
MAR
APR
MAY
JUN
JUL
AUG
SEP
OCT
NOV
DEC
TOTAL
PAGE NO.
C'ArS/MO
31
28
31
30
31
30
31
31
30
31
30
31
365
3 OF 8
PRECIP-
TTAT TOM
1 1 H 1 1 UIM
IN/MO
O.52
0.55
O.61
0.58
O.46
0.40
O.91
1.O1
0.96
0.99
0.45
0.63
8.07
LAKE
C\t£\C'
tVHn •
IN/MO
O.96
1.56
3.79
6.34
8.01
8. 83
8.73
7.38
5.71
3.79
2.03
0.99
58. 12
DISPOSAL
1,1/VTC'C'
WH I tr\
BBLS/DA
750. OO
750.00
750.00
75O.OO
750.00
750.00
75O.OO
750.00
75O.OO
750. OO
750.00
750.00
CUM.
nc"n'Xi-i ncDTu
Utn 1 n Utr 1 rl
FEET FEET
_
3.09
2.74
2.86
2.55
2.50
2.32
2.48
2.6O
2.63
2.89
2.89
3. 10
SPRAY E
i noo r
LUoo L
FEET
-1.43
-2.58
-2.86
-5.53
-5.72
-8.30
-8.58
-8.58
-5.53
-8.58
-1.38
-1.43
:VAP.
*l IM nOTU:
rfUn . ur 1 *:
FEET
3. IE
4. £4
5 . 0 :
5 . 0 .
2.01
0 . 0 '.
O. O1-
o.c--
o.o.
o. o :
o. o<:
1.51
3. IS
~~
C-665
-------
WAVE CALCULATION "
(ALL REFERENCES-SHORE PROTEDTION MANUAL)
UJIMD3PEED, Ua= 50 M.P.H. : FETCH, F= 336 FEET
DEPTH OF WATER, D = 11.00 FEET SLOPE OF SIDE =3:1
l.'-VE HEIGHT AND PERIOD.
PCF. D = 0.1 TO 5.0 FT., Pg. 3-56, Fig. 3-27 (UPPER)
FOP D = 5.1 TO 10.0 FT., Pg. 3-57, Fig. 3-29(UPPER)
MAVE HEIGHT, H= O.4O FEET
FE". :OD, T= 0.8 SECONDS
Cr^_CL'L^-TE BREAKING WAVE HEIGHT, Hb (Pg. 7-7, Fig. 7-3)
H
= 0.0194 g= 32.2
a x T'--2
Hb
(Fig.7-3) = 1.0 NOTE: UTILIZE ~(m = 0.1) FOR SLOPE OF
H SIDE = 10:1 OR LESS.
Hb
Hb = H x = 0.4
H
Hb
= 0.0194
g x T'^2
Pg. 7-6, Fig. 7-2 (UTILIZING m = 0.10(1:10))
a= 1.6 a = alpha, upper limit
b= 1.05 b = beta, lower limit
BREAKING HEIGHT, -ft, MAX. =axHb=1.6x 0.4 = 0.6:
BREAKING HEIGHT, -fT, MIN. = b x Hb = 1.05 x 0.4 = 0.4:
COMMENTS:
D = 11. OO -feet is average depth o-f water in pond.
(ELEVATION-5719.5')
PAGE NO. 4 OF 8
C-666
-------
NON-BREAKING WAVE FORCE AND MOMENTS
(ASSUMING A VERTICAL WALL)
(ALL REFERENCES SHORE PROTECTION MANUAL)
Fg. 7-161
X = 1.0 (ASSUME SMOOTH WALL)
Hi = H = 0.4
d = 12.5 FEET
T= 0.80 SECONDS
Hi 0.4
= = 0.0320
d 12.5
Hi
= O.O194 g =
g x T-'-2
Pg. 7-164, Fig. 7-9O
Ho
0.30
Hi
Ho
Ho = x Hi - 0.12O FEET
Hi
Pg. 7-161, Equations 7-73 and 7-74 and
Pg. 7-162, Fig. 7-88
HEIGHT OF CREST ABOVE BOTTOM
< 1 + X )
1 Yc = d + Ho + ( ) x Hi = 13.02 FEET d = 12.
' < 2 ) (ELEV. - 5720.02') Ho = 0.11
- X = 1.
I HEIGHT OF TROUGH ABOVE BOTTOM Hi = 0.
, ( 1 + X )
] Yt = d + Ho - < ) x Hi = 12.22 FEET
J ( 2 ) (ELEV. - 5719.22')
| COMMENTS:
d = 12.50 feet is at the east end or deepest portion
of the pond. (ELEVATION - 5719.5')
PAGE NO. 5 OF 8
C-667
-------
j (AT WAVE CREST)
Fg. 7-165, Fig. 7-91
! Fc Hi Ho
= 0.001 = 0.0194 = 0.30
j w x d 2 g x T~2 Hi
Fc = 0.001 x w xd~2 = 10.44 Ib./ft w = 66.8 lbs./ff
j d = 12.5 FEET
COMMENTS:
] force is considered negligible.
PAGE NO.6 OF 8
C-668
-------
BERM CALCULATIONS
#fiIIHUH HEIEHT « 11 FEET
\ TOP HIOTH = 12 FEET
•AX. HATER DEPTH = 9 FEET
1 ( ON BERM )
JftTER DEPTH - FT. 1 2
;EPTH BELOW
1RFACE - Ft.
1 67
] 2 0
« 3 0
4 0
! 5 °
1 6 0
7 0
I 8 0
1 9 0
10 0
\ ll °
' 12 0
ITATIC PRESSURE 67
*b LINEAR
:OOT - Lbs./Fl. = Fh
67
134
0
0
0
0
0
0
0
0
0
0
201
1 iiEIGHT OF
PER
1
a
1 DEPTH FROil
TCP OF
| ScRH
Ft.
i i
i 2
3
i 4
' 5
. 4
7
3 8
, '
.0
- 11
12
LINEAR
INSIDE SLOPE *
OUTSIDE SLOPE •
3 4
67
134
200
0
0
0
0
0
0
0
0
0
401
BERN
FOOT
Lbs.
1200
2880
5040
7680
10800
14400
18480
23040
28080
33600
39600
0
67
134
200
267
0
0
0
0
0
0
0
0
668
3 -I SOIL DENSITY «
3 -I FRICTION FACTOR »
STATIC PRESSURE - Lbs./Ft.A2
5678
67
134
200
267
334
0
0
0
0
0
0
0
1002
SHEARING
DEPTH FROM
TOP OF
BERH
Ft.
1
2
3
4
5
6
7
8
9
10
11
12
67
134
200
267
334
401
0
0
0
0
0
0
1403
FORCE,
67
134
200
267
334
401
468
0
0
0
0
0
1871
Fs
Fs
480
1152
2016
3072
4320
5760
7392
9216
11232
13440
15840
0
67
134
200
267
334
401
468
534
0
0
0
0
2405
80 Lbs/Ft.A3
0.4
9 10
67
134
200
267
334
401
468
534
601
0
0
0
3006
0
0
0
0
0
0
0
0
0
0
0
0
0
It
0
0
0
0
0
0
0
0
0
0
0
0
0
12
0
0
0
0
0
0
0
0
0
0
0
0
0
f
6E 7 OF 8
C-669
-------
•JATER DEPTH - FT.
-i BERN
1tI5HT - Ft.
t
2
3
4
5
4
7
3
9
10
11
12
1 2 3
SAFETY FACTORS - Fs/Fh
4 5 4 7 (
I 9 10 11
7.14
17.19
30.09
45,85
64.J3
85.97
110.33
137.35
Ii7.o4
200.60
23J.42
v.OO
5.73
10.03
15.28
21.49
28.46
34.73
45.85
55.28
64.87
78.81
0.00
5.03
7.64
10.77
14.34
18.43
22.98
28.01
33.52
39.50
0.00
4.60
6.47
8.62
11. T
13.SO
16.81
20.12
23.71
0.00
4.31
5.75
7.38
9.20
11.21
13.41
15.81
0.00
4.11
5.27
4.57
B.01
9.58
11.29
0.00
3.95
4.93
6.00
7.18
8.47
0.00
3.83
4.47
5.59
6.59
0.00
3.74
4.47
5.27
0.00
0.00
0.00
0.00
0.00
0.00
NQfE: TOP OF 8ER« - ELEVATION, 5722'.
NAIIHUH HATER LEVEL - ELEVATION, 5719.5.
j
^ASE 8 OF 8
C-670
-------
J^t -~r •-•-»*~-tf»* "
3^: LJ . i. .-^j- -t-^i[ i • • * rr:^
BASIN BISPOSAl, ISC. ^ ,'.
Korth-South Froftl«
August 14, 1585 •
-------
if=KteT=3E£ 25FJBK
s»l
T"^X3v* -t~-:P4J-^ • r7 .J-K^---*—•—--——
: Sorth-Seuth tia I tl« 'i':S-
, 1985 >
-------
BASIN DISPOSAL, INC.
North-South Profile C-C
August 14, 1985
300
-------
^ BASIN DISPOSAL, INC.
North-South Profile D
August 14, 1985
Figure No. 5
250
-D1
-------
BASIN DISPOSAL, INC.
West-East Profile V-V'
August 14, 1985
Figure No. 6
400
-------
BASIN DISPOSAL, INC.
West-East Profile W-W
August 14, 1985
-------
{i
\
o
400
-------
£,-.<*-, •-.} ^ip^g
Sl Kd ! fc^l- — :g^
BASIN DISPOSAL, INC.
West-East Profile Y-Y1
August 14, 1985
Figure No. 9
-------
. '• AV\.» A«'\ i • • i* r«\ • H i •\\iiiii.Mli". 11. • • 1! i -11 • ''••• IJ' • I • - i' I' -'' • i -' *' >' •'!' i'' '!•-'' '
o
i
vo
BASIN DISPOSAL, IMC
Slope Protection un
Liner Anchor
-------
1
Liner
BASIN DISPOSAL, INC,
Vents
C-680
Figure No.
-------
00
•. .-•••• *
BASIN DISPOSAL, INC.
Leak Detection Systea
Figure No. 12
-------
BASIN DISPOSAL, INC.
Pond Inlet and
'
'*«'.»! ° .
' ' ****•» ' . "
-------
HASIM DISPOSAL, INC.
Leak D e L e c c J. o n S y s r. e in
Thru Berm and Sump
Figure No. 14
-------
vt
>ii^g«E^SJ~=iij>g^^=
—=^*' -11- -;- ..--•-* ^T•. !.
BASIN DISPOSAL, INC.
Sk.Ioiaier Tanks
Figure No. 15
-------
ENGINEERING & PRODUCTION CORP.
Pstroleum Engineering Consulting
Lease Management
Contract Pumping
3001 Mon-^inclqe Dnve
PO Drawer J! 9
Farmington New Mexico 37401
[5Q5j3S7-48Sa
August 19, 1985
J 1.*!* -
Mr. Phil Eacca
Environmental Engineer
Oil Cor. servation Co mm i s s i o n
P. 0. Eox 2088
Santa Fe, New Mexico 87501
REF: Basin Disposal, Inc.
Proposed Disposal Pit
Unit E & F, Section 3-T29N-R11W
San Juan County, New Mexico
Dear Mr. Bacca:
The enclosed revised Figure No. 12, Leak Detection System, is
being submitted for your approval as per our telephone conversation
on this date.
I believe the revision, dated August 19, 1985, will meet the
requirements as to 20 feet distance of leak detection system from
any portion of bottom of pit.
Thank you for your consideration in this matter.
Very truly yours, /?
Ewe 11 N. Wais h, P.E.
Pre sident
ENW:rr
cc: Frank Chavez, OCD, Aztec, N.M.
Basin Disposal, Inc.
Jerry Sandel, D. C. Turner and David Turner
Enclosure
C-685
-------
BASIN PIS'-O-'AL,
Leak Det £ ct :en Sys
Figure No. 1-
(Revlsed 8 ' ! 5 .' E 5 1
-------
g
\ 5
i .O
Figure Sc. 12
(Revise- i i 1 r. : '.
-------
WALSH
ENGINEERING & PRODUCTION CORP. Petroleum Engmeering Consulting 3001
Lease Management
Contract Pumping (5Q5) 327-489;
BASIN DISPOSAL, INC.
PRODUCED WATER EVAPORATION PIT
PROPOSED
WATER SPRAY SYSTEM
SAN JUAN COUNTY, NEW MEXICO
November 21, 1985
Ewell N. Walsh, P.E.
State of New Mexico
Registration No. 4324
C-688
-------
INDEX
Preface
Summary
Location
Design and Construction
Motor and Pump
Motor and Pump Location
Spray System
Mainline
Spray System
Schematic - Perimeter Spray System
Spray Array
Evaporation Rate Vs. G.P.M. - 24 Hrs,
Evaporation Rate Vs. G.P.M. - 12 Hrs,
PAGE NO.
1
2
3
3
3
3
3
3
3 and 4
FIGURE NO.
1
2
TABLE NO.
1
2
C-689
-------
PREFACE
The purpose of installing a spray system at
the disposal pit is to increase evaporation rate,
into the air, and maintain a water level below
approved maximum water level.
C-690
-------
-2-
SUMMARY
Installation of the proposed spray system will prevent
the water level from increasing to the approved water level
for the pit.
Installation of the system in the top of the berm will
not affect the stability of the berm to contain disposed
water.
It is anticipated, depending upon temperature and
relative humidity, to evaporate 500 to 2500 barrels per
day.
C-691
-------
-3-
LOCATION
The approved water disposal pit is located in an area
of Units E and F, Section 3-T29N-R11W, San Juan County,
New Mexico.
The area is located adjacent to State Highway 44,
approximately three miles north of Bloomfield, New Mexico.
DESIGN AND CONSTRUCTION
1. Motor and Pump:
A. Fifty (50) horsepower electric motor.
B. Two stage centrifugal pump.
Rated Capacity - 600 gallons per minute at
70 to 75 psi.
C. Installed on concrete base.
D. Enclosed for weather protection and heated
to prevent freezing.
2o Motor and Pump Location:
A. Installation is proposed on top of berm
at northwest corner of disposal pit.
3. Spray System:
A. Mainline:
1. Mainline, 4", Class 200, P.V.C. pipe, to
be installed on top of berm at 2 foot
depth, for the full circumference of pit.
2. Mainline drain will be installed at south-
west corner of pit to drain system to
prevent freezing of main line during
shut down periods.
3. Water drained from system, to be contained
in above ground, plastic or similar
material, tank or container.
4. Mainline to be installed a minimum of 2 feet
outside of trench containing pit lining
anchor.
B. Spray System:
1. Fifty (50) individual spray arrays will be
installed around top of disposal pit.
2. Spacing between arrays will be 20 feet.
3. Each array will connect to mainline with
3/4 inch diameter, schedule 80 P.V.C. or
3/4 inch galvanized pipe.
4. Each array will have control valve for
shut off if wind direction and velocity
will have an effect on spray blowing outside
of pit.
C-692
-------
-4-
5. The spray array will consist of (six (6)
half-circle spray heads to spray\towards
center of disposal pit. Each spray head is
rated at 2 gallons per minute at 70 to 75 psi.
6. The spray array will be installed so that the
array will be 5 to 6 feet, from the pit side
of berm, inside the area of lined pit.
7. The connecting line will either drain into
the mainline and/or into the disposal pit
when pump is shut off.
C-693
-------
HoW
N
"_:_r r i r~i.:.i:~.l T;T;
r-
i
o
i r. i. i:r i ~r:rr:
..._.J
Uioa ->•
__LEG END
±f.Hlc<> -^PKirttL*-* He. MI
i"/.-(v,-» .'.oo fVi
FIGURE NO. 1
Schematic
Perimeter Spray System
-------
AJ.T. S.
(A)
5
So
P,V,C.
FIGURE NO. 2
Spray Array
C-695
-------
TABLE NO. 1
EVAPORATION RATE - BARRELS PER DAY(24 HRE
EVAPORATION RATE - %
GFM
100
200
300
400
500
600
700
800
900
1 000
1 1 00
1200
1 300
1400
1500
1600
1 700
1 SOO
1900
2000
5
171
343
514
686
857
1029
1200
1371
1543
1714
1886
2057
•""!*•"? O Q
2400
2571
2743
2914
3086
™T'*-n^-7
• J- ji. uj /
3429
10
343
686
1029
1371
1714
2057
2400
2743
3086
3429
3771
4114
4457
4800
5143
5486
5329
6171
6514
6857
15
514
1029
1543
2057
2571
3086
3600
4114
4629
5143
5657
6171
6636
7200
7714
8229
8743
9257
9771
10286
20
686
1371
2O57
2743
3429
4114
4800
5486
6171
6857
7543
8229
8914
9600
10286
10971
11657
12343
13029
13714
ji!-_j
857
1714
2571
3429
4236
5143
6000
6857
7714
S571
9429
10286
11143
12000
12857
13714
14571
15429
16286
17143
3 O
1029
2057
3086
4114
5143
6171
7200
8229
9257
10286
11314
12343
13371
14400
15429
16457
174S6
18514
19543
20571
*-'vJ
1 200
2400
3600
4300
6000
7200
S400
9600
10800
1 2000
13200
14400
1 5600
1 6800
18000
19200
20400
21600
22800
24000
C-696
-------
TABLE NO. 2
EVAPORATION RATE - BARRELS PER DAY(12 MRS,)
EVAPORATION RATE - 7.
GPM
1 00
200
300
400
500
600
700
800
900
1 000
1100
1200
1300
1 400
1500
1600
1700
1800
1900
2000
5
36
171
257
343
429
514
600
686
771
857
943
1029
1114
1200
1236
1371
1457
1543
1629
1714
10
171
343
514
686
857
1 029
1 20O
1371
1543
1714
1886
2057
*-> 0 ^ C5
2400
2571
2743
2914
3086
3257
3429
15
257
514
771
1029
1236
1543
1300
2057
2314
2571
2329
3086
3343
3600
3857
4114
4371
4629
4336
5143
20
343
686
1029
1371
1714
2057
2400
2743
3086
3429
3771
4114
4457
4800
5143
5486
5829
6171
6514
6857
25
429
857
1236
1714
2143
2571
3000
3429
•±>oo /
4236
4714
5143
5571
6000
6429
6857
7236
7714
8143
8571
30
514
1029
1543
2057
2571
3086
3600
4114
4629
5143
5657
6171
6636
7200
7714
8229
3743
9257
9771
10286
35
6OO
1200
1 8OO
2400
300O
36 OO
420 O
4SOO
540O
6000
660O
7200
7800
8400
900O
9600
1 0200
10800
11400
12OOO
C-697
-------
I.' L I r il •» 3 ---• r i-
c J ,i 1 . u • -
i) r J ! >i 11:
"
:-£---.
V
* M.
: & ? / \
v
K
~**- __.
M M. STATS HWY
£ £9' 5V
.. 26/7.
I
oj ij-..»- -j- :'- .•_, • 'I-.'-'?
a\
VD
oo
BASIN J.SP:SAL, IN:C.
?iac o: Acroiige with
Tc^ogrs^liy, OLicitie oc
FLC an: Pr:f-LLe Li.ies
tt?It Outline
"Profiles
--X th. Sou * 330 r«t of th. HartJw.rt
?., S*n Jtu-i CO^-.T, x^ Haxljo, !..< and
of rn»rd or In «lit*no«.
8«tiw J,
MT «nd ^1
«•*• II, do h«r»by cartjfy that Tut Pro*«««lOMl Land 3iu mjur
IMdar Xh« L
-------
Ditch i 5ero
to divert
'"^ \X".v
/ , ffl
/f
n
v
\
', ^ 26/7.05-
n
i
•rhtrii ny, outline of
Pic and Jrofile Lines
August 14, 1935
I
£
DES.CRIPTION |;
A tr»ct of land txinf th« ScntA 330 feat of th* Horthwsrt (}MTt«r «f 8*oti*n 3.
TJ9S, P.11W, N.M.P.M., S«n ^^^ntT. «« M.xt«o, !••« and axocpt «ny and aU
-------
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''ief./if " ' "' --r- .•••- f --'.<- • '-'. • :• -,-,.•'. V ,..-:'
BASIN DISPOSAL, I
Plat of Acreage
Topography, oucl
Pit and profile
Augusc LA, 1935
DESCRIPnOK •'
•'--*-. .;--''':''-•: .if, ,'&':$£':' '•-"„ ' .-.'..•; "vV-r>;°? ;•;•-" '£ Y> - • :;*,../.' '-'v-'?'.','-'1" ? •. . r * **^ ^ l»J>d Wlnj W*»tf%vi *~.
" ;?\.-.;-. .'-^ ' -;a l-'KiiN^- ....-••••'• .;•:•'.>£•. :,r, ;•.:.:£-, ..'Y ,' ;.. :--?%. ,{>->':/?• VV^,;-: v •"-•;*»*. mv, B.M.T.X* $„, ^Miti ;
>•*••£• :S:Y:;*$f* vi^£-£\k*4*^&:r%"•";fe.^4^r"v^ ,4^ir^nu«:-"^-^«-.•*-f^^L
K|:C|;|;;|;
-------
ENGINEERING & PRODUCTION CORP.
Petroleum Engineering Consulting
Lease Management
Contract Pumping
30C' Norvrtge Onve
eaco 874
(505(327-4892
August 16, 1985
Mr. Phil Bacca
En v i rcrien tal Engineer
OIL Cor.nervation Division
P. 0. Box 2088
Sirt-.a Fe, New Mexico 87501
REF: Basin Disposal, Inc.
Proposed Water Disposal Pit
Unit E & F, Section 3-T29N-R11W
San Juan County, New Mexico
Dear Mr. Sacca:
Enclosed you will find, as per your request during our meeting
August 15, 1985, .three copies (3) of revised Contingency Plan and
drawing of Leak Detection System, Figure No. 12.
In addition, as discussed during our meeting, the following
changes are requested to be approved:
1. Secondary liner to be 20 mil. thickness instead
of 30 mil.
2. Slope of grade for Leak Detection System to be 6"
per 100 feet instead of 6" per 50 feet. Note: 6"
per 100 feet is approved by the Texas Railroad
Commission for Leak Detection Systems.
Also you indicated that you would advise as to type or degree of
water anaylsis you would require concerning the analysis of water de-
tected in detection sump.
Thank you for your consideration and cooperation in these matters
Very truly yours, >
Ewell N. Walsh, P.E.
President
ENW:rr
cc: Frank Chavez, OCD, Aztec, N.M. w/encl.
Basin Disposal, Inc. w/encl
Jerry Sandel, D. C. Turner and David Turner
C-701
-------
CONTINGENCY PLAN
If fluid is found in detection sump a sample will be
obtained and analyzed to determine if the fluid is the
same, fluid that is in the disposal pit. The O.C.D. District
Office, Aztec, New Mexico, will be immediately notified of
the detection of fluid in the detection sump and will be
furnished a copy of analysis of fluid.
If fluid is determined to be the same as in the disposal
pit :
a. No additional water will be put in disposal
pit.
b. The spray evaporative system will be utilized
to evaporate water as fast as possible.
c. If spray evaporative system is not removing
fluid at a sufficient rate, frac water storage
tanks will be utilized as storage for removal
of water from pit.
d. When water has been removed the pit and liner
will be inspected and any repairs will be made
as per liner manufacturer recommendations.
\
c_702 Revised 8/16/85
-------
^3=^^i
Figure No. ];
(Revlsed F ' it/£ 5)
-------
o
w
i
BASIN sis! ?;.•.:.
Leak Det c c t i - r.
FJgure No. ;:
(Revised f '
O
-------
ATTACHMENT D:
EVAPORATION PIT GEOLOGICAL REPORT
C-705
-------
C-706
-------
r
EVAPORATION PIT
GEOLOGICAL REPORT
SECTION 3-T29N-R11W
SAN JUAN COUNTY, NEW MEXICO
JULY 23, 1985
L J
f
' on. CONSERVATION DW1SW&
R. Tucker Attebery, Geologist
ATTEBERY GEOLOGICAL SERVICES, INC.
3005 Northridge Drive - Suite L
Farmington, New Mexico 87401
505-327-4039
C-707
-------
EVAPORATION PIT GEOLOGICAL REPORT
for the south 330 feet of the northwest quarter
Of section 3-T29N-R11W, San Juan County, New Mexico
The property is located two and one-half miles north
of Bloomfield, New Mexico along the west flank of the valley
bisected by Highway 44. Due to the gentle slope, surface
drainage is primarily a sheetwash from an elevation of
approximately 5740 feet to 5720 feet in a south-southwest
direction.
Three miles south, at an elevation of approximately
5500 feet, the San Juan River Valley represents the closest
vulnerable ground-water system and floodplain. Drillers
logs from the 1920's indicate reaching a water table below
250-290 feet in wells drilled just north of the property.
This apparent aquifer or saturated zone probably coincides
with the mean water level of the San Juan River.
No successful water wells have been drilled within a
three mile radius according to the 1984 publication
"Availability of Hydrologic Data in San Juan County, New
Mexico". The area has been approved for septic systems
and successful systems surround the property-
The soil cover is zero to 15 feet of well drained,
sandy loam on gently sloping topography. This soil is
classified as "Stubble-Fruitland" in the 1980 publication
"Soil Survey of San Juan County, New Mexico". The soil
cover is underlain by and seperated from the apparent water
table by about 250 feet of gray, sandy, clayey shale
containing thin, scattered, discontinuous, sand and silt
lenses. It is the weathered and erosion thinned too of the
Nacimiento Formation of Tertiary Age. The limited oermeability
of this unit provides a thick vadose water zone.
The vadose water zone .is defined as a zone periodically
containing suspended water in the zone of aeration, and is
above the zone of saturation (water table). Because of it's
thickness, in this case, any organic or inorganic contamination
will be reduced in strength by a delay in movement and therefore,
are subject to dilution, mixing sorption, volatilization and
microbiological degradation.
In our opinion, the property is acceptable for evaporation
pit usage because of the surface stability and isolation from
surface and subsurface waters. It is several miles from any
area, considered by the state, to have vulnerable ground waters,
The vadose zone isolates the shallowest possible aquifer and
already is part of an approved septic system zone.
C-708
-------
ELEV/VHoN
•58oo'
-57-10
-3720'
or-> f
V<=rt. Scale \" * ioo'
00 CobVjles * So'.V <£TD
-f \ooti
55CX3
5400'
Hor\-ior\VA Scale. - oox-»e.
Verses • - • Water ii.nJl --
-Z -
C-709
-------
C-710
-------
ATTACHMENT E:
BILL OF LADING USED BY BASIN DISOSAL, INC,
C-711
-------
C-712
-------
CAS IN DISPOSAL. INC.
P. O. BOX 100 • AZTEC, NEW MEXICO 87410 • PHONE: (SOS) 334-3013 NO.
LOCATED 3 MILES NORTH OF BLOOMFIELD ON WEST SIDE OF NM HWY 44
2286
DATE.
O
I
-J
U)
CUSTOMER.
WELL NAME & NUMBER
TRUCKING CO.
DRIVER
ORDERED BY
ATTENDANT'S SIGNATURE
UNIT NO.
DEL. TICKET NO.
NQ.
1
2
3
4
5
6
WATER
MUD
TIME
AM
PM
DRIVER'S SIGNATURE
LOADS @ $50.00 =
LOADS @ $75.00 =
TOTAL =
dj? -
Xj
tP
Bin Juan rapr Form 166-1
-------
C-714
-------
Sampling Report
Investigation of Amoco Production Company's
USG Section 18 Well No. 43
San Juan County, New Mexico
June 26, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active San Juan Basin production sites developed by the
New Mexico Oil Conservation Division at the request of EPA. The
list was transmitted via telephone to the EPA contractor on June
10, 1986. Site selection from this list took place during the
telephone conversation.
New Mexico state officials preferred to list the possible sample
sites as shown below. The EPA contractor had no interest in the
manner the particular sites were listed (by site name, location,
operator, permit number, API number, etc.) as long as the site
could be identified in detail upon selection. Thus, the EPA
contractor had minimal information which kept to a minimum the
amount of bias. No other information was known about the sites
on the list at the time of selection. Detailed information was
obtained only after selection of primary and back-up sites. The
list consisted of eight production sites in northwest New Mexico:
1. Pump Mesa
2. Cedar Hill
3. Hogback Unit
4. Cha Cha Gallop
5. Galletos Canyon
6. Totah Gallop Field
7. NW Cha Cha Unit
8. Mexico Federal
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
No. 8 on the above list (Mexico Federal) was selected as the
primary sample site. No. 5 on the above list (Galletos Canyon)
was selected as a back-up site.
Further inquiry indicated that both the primary and back-up sites
were inappropriate for sampling. The particular wells at both
proposed sample sit.es were not producing (shut in).
The EPA contractor randomly selected a second back-up site from
the original list of sites and the random number table. The
second back-up site was No. 3 on the above list (Hogback Unit).
C-715
-------
Further inquiry indicated that this site was Amoco Production
Company's USG Section 18 Well No. 43. Arrangements were made for
this site to be sampled June 25, 1986. (See Sampling Information
regarding actual sample date.)
The New Mexico Conservation Division conducted a reconnaissance
visit to the site to confirm its appropriateness and availability
prior to sampling. Sampling was conducted on June 26, 1986. No
back-up site was required.
Site Location
USG Section 18 Well No. 43 is located 23 miles west of
Farmington. Figure 1 is a map locating the production site.
The site is operated by Amoco Production Company, whose mailing
address and telephone number are:
501 Airport Drive
Farmington, NM 87401
505-325-8841
Contact: Ed Alizadeh, Engineer
Attendees
Sampling of USG Section 18 Well No. 43 was performed by CENTEC
Corporation personnel on June 26, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
Andy Procko, Engineering
Manager, Acting Technician
EPA Representative:
State Representative:
Operator Representative:
American Petroleum
Institute Representative:
Site Description
Susan de Nagy, Office of Water,
Project Officer
Dave Boyer, NM Oil Conservation
Division
Ed Alizadeh, Production
Engineer
Bill Freeman, Contracted
Observer
USG Section 18 Well No. 43 is located within the San Juan Basin
in an area characterized as a rural mesa. The depth to
groundwater is over 100 feet, and the nearest surface water is
less than 1/2-mile away. There are no drinking water wells
within a 1-mile radius of this site. The soil in this area is
C-716
-------
THE. HOGBACK NORTW QUADRANGLE
NEW MEXICO-SAM JUAN CO
TJ MINUTE SERIES (TOPOORAPHIQ
-» 'wSVi;^rt-v'A \'>.-f-.y-\~ 7. >6':;--
1 .TVW1 ,'t-^.l ' * A i .V ('__ • *•—'- - , -V ' I ..'} J I ' ^ ^f •
•A.. ^•'•^M^M*^^ -/ J£'
-------
mostly sandy rock. The climate at this site location is net
evaporation.
This site consists of an actively producing oil well with a
production of between 60 and 70 bbl/day. Daily production of
produced water ranges from 70-80 bbl/day. Production at this
site is sweet. The well depth is 7283 feet. The well produces
using natural drive. The lease for this well contains a total of
12 wells, 4 of which were producing at the time of sampling.
Figure 2 is a schematic diagram of the production facility. The
site consisted of a 400 bbl gun barrel tank (shown in Photos 1
and 2 in Attachment A), and two 400 gallon oil storage tanks.
Disposal Practices
As of the time of sampling, this site was approximately 1-year
old, and their current system of produced water disposal was
classified as temporary. The produced water was collected in the
gun barrel tank prior to being trucked to a central pit or
central treatment facility. The tanks at this site had never
been cleaned.
Permits
The associated drilling and completion permits for the well are
shown in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The sample collected at USG Section 18 Well No. 43 consisted of
one liquid sample. The sample collection point was at the gun
barrel tank.
Sampling Methods and Equipment
The liquid sample was collected at a valve at the bottom of the
gun barrel tank. The liquid thief was not used, since there was
only 5-10 feet of liquid height in the tank at the time of
sampling. The sample bottles were filled directly from the
valve. Originally, sampling was to have been conducted on June
25; however, the tank was emptied on June 24 because the well was
temporarily shut down. The well was restarted on June 25.
C-718
-------
\AJELL
O
I
-J
OIL
STOCK
TANK
H006KL
TKEE
ROAD
Figure 2. Schematic Diagram, USG Section 18, Well No. 43
-------
An attempt was made to take a tank bottom sample from the top of
the tank using a dredge. However, the tank had no bottoms to
collect.
The pH of the produced water was tested onsite after the
completion of sampling. The results gave a pH value of 6.
C-720
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-721
-------
C-722
-------
Photo 1. Sampled brine tank
Photo 2. Sampled brine tank
C-723
-------
0724
-------
ATTACHMENT B: PERMITS
C-725
-------
C-726
-------
STA7C Or NEW MEXICO
ENER'JY AM) MirJLHAI.3 DEPARTMENT
OIL CONSERVATION DIVISION
P. O. wO X 20BH
SANTA FE. N^W MEXICO 87501
ft* mutl be from Ih • oulrr tiOi*v1*rlrt «cd pencil or hachure marks on the plat below.
2. If more than one 'cafe; is dedicated to die well, outline each and identify the ownership thereof (both as to working
interest und royalty). *
3. If more than one lease of different ownership is dedicated to the well, have the interests of all owners been consoli-
dated by communitization, unitizaticn, force-pooling, etc?
| | Yes | | No If nnswcr is "yes" type, of consolidation _
If answer is "no" list the owners and tract descriptions whirh have actually been consolidated. (Use reverse side of
this form if necessary.)
No allo.k-oblo will be assigned to the well until all interests have been consolidated (by communitization, unitizntion,
forced-pooling, or otherwise) or until a non-standard unit, eliminating such interests, has been approved by the Division.
I t
1 '
1 NQ
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f^ &*.£' n ? • T* F^-N
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CERTIFICATION
/ fiereby certify that fne Information corf
(o/ne fS« l*«sf of my
fcnowivo'g* ono* b*/
-------
i --• KM) \ HNITFD STATES diJBMiT if r«iiM.ir*re-
(K..-"|,-.,-JH, DEPARTMENT OF THE INTERIOR "" /
HURCAU Of LAND MANACCM(:HT ^/
SUNDRY NOTICES AND REPORTS ON WELLS
U- -ATrlJCATIOH FOK rKMMIT.-" l.r *lpfc»—V^ U. 1 » I— B^
1 . • _
..i fvi «•• n " 1FP 1 fi l^flS
-in. uy -«LC LJ •«••€« - -•• jcu J- u uoj
Amoco Production Co.. - ( BUREAU Of UNO MANAGEMENT
i. ........ or o,...™. - ---- fARMINGTON RESOURCE AREA
501 Airport Drive, Farmington, N M 87401
AT alM «p«r» 17 brl«w.(
At *urf*rr
1500' FNL X 1760* FWL
14. rctiJiT *o. U^ «LCv*not** (Sbo«- whether or. *r. c«. etc.)
5176' GR
-Xf«j.t"JTO« iCIUll*
«cr*i« "CLL
lOfh»r)
IT trctt fti*c ror-osro <
aHOOTdNC O* ACIOUIR4
fcMPAflinO WILL
ALPKCIHC CA«IF»O
AV&HOOP W •WT*
X
( Nort : Report rrvolu of maJtlpU cocnplrCloo oa Weil
Completion or Rrcoupictloa Export «.od I»c form.)
ilj nar*- «ll r^r(l,,^,,( 4^t«ll«. «nd rl«"' p^fttorot d««-«. Uctudloc rvflaftt*** d«te of «UrUt»c *o;
.",.,v,.,; in r.nd rigged up service unit on 11-11-85. Filled annulus with 29 bbl
KCL and released^packer. Killed well with 160 bbl 95% KCL and landed cast
iron bridgeplug and packer at 6694'. Acidized perforations 6646'-6656' with
98 bbl 28% HCL. Moved packer to 6528' and acidized perforations 6646'-6656',
6610'-6616', 6573'-6582' with 200 bbl 28% HCL and flushed with 160 bbl 2%
KCL. Killed well with 320 bbl 9.5% KCL and 100 bbl 10.4# brine. Released
packer set at 6694'. Landed 2 7/8" tubing at 6252' and packer at 6252'. Re-
leased the rig on 11-21-85.
^f -hfttttf crrct//
.* M; SI-TO ^ _
I 7^» §P«CT for Trd
±
0£c i 9 J985
CON. D/V
DJST. 3 '
fUA
,\j*^t TITLK _..Adm_. _S_u_p_ervisor ()<
11-27-85
Or 4PPROT1U IT AXT:
TITLB
DATK
C-728
*Se« Inifrvctiont on RCVCTM Si«l«
l.°°'1 """* V ' C"me f°' •"' p""n k*VA,Viid wi'lifuVlV «• m.k. .. ,ny
..cniiout o> fr.udul.nl >laicm«nli or rr p,»» ,n« .1,00. .« to «nr mJKff ~i ttuj
-------
rJ-=n3160-4
(November 1983) ._,__ <.._.-._£._ -SUBMIT IN DUPLICATE*
(fonMrly 9-330) UNITED STATES /° (S (( f
DEPARTMENT OF THE INTERIOR ;;;-;—,
BUREAU OF LAND MANAG^tfENT """" ""
WELL COMPLETION OR REGOMPL^TfON REPORT AND LOG *
- - - --'^ - *" ° '""'
U. TYPE OF WELL:
b. TYPE OF COM^LETIO^r^;^f'
.vrw |—i W..UK -
2. NAME OK OPERATOR I A1'
. \y\ :
Amoco Product i on i. Company
. . -. • ill I j
. \y\ r.zr: Q;) U:o ihll
MJ
3. Aiiunens or OPERATOR \ ,
CON.
„„,.
501 Airport Dr i v^r^^In^fS.H^'JMNr''- •;g'?l^ 1 P*ST« 3
4. IXJCATIO.X ur WKI.L (RrporT location c/c^r/^^fl^dj'* ffcortlunct with any SKXII;NATIUN ANH SCKIAI. NO.
I-89-IND-58
li. IF IMHAN. AI.I.OTTKE OR TRIUB N A M F.
____
7. ("SIT A-.KEKMtNT NAME
> KAUM OR LKA.HC NAME
USG _Secl[on_ _\&
9. WELL NO.
_43
10. riELO AND POOL. Ot WILDCAT
Hogback Penn
Tl. SKI'.. T., R.. U., OK DLOCK AND SUHVET
OR AREA
SE/NW Sec 18, T29N, R16W
12. COl'NTT OB
PAK1SH
San Juan
13. STATE
NM
13. DATE SPCDDED
7-18-85
16. DATE T.D. REACHED
8-18-85
17. PATE
9-16-85
(DC. RKB. RT. Gl, ETC.)'
5189' KB
19. ELEV. CASINOMEAD
5176' 6R
20. TOTAL DETTH. MO * TVD
7283
21. rLUO. SACK I.D.. MD * TVD
7271'
22. IF MCI.TIPI.E COMPL..
HOW .MAST*
Si ngle
23. INTERVALS . KOTART TOOLS
DRILLED flT
CABLE TOOLS
0-TD
24. PRODUCING INTERVAL(S). Or THIS COMTLCTION TOP. BOTTOM. .NAME (MD AND TVD)«
6573'-6656' Penn
25. WAS DIBECTIOXAL
SUEVET MADE
Yes
28. TTPE ELECTRIC AND OTHER LOGS Kl'N
FDC-CNL; PIL-GR-SP-CAL; Dipmeter
27. WAS WELL CORID
NO
2.1.
CASINO RECORD (Report all firings let in terll)
CASINO SIZE
13-3/8"
9-5/8"
7"
WEIGHT, LS./fT.
48#, H40
36#, K55
23#, 26#
29.
SHE I TOP (MD)
Flowing through 7"
1
, K5
DEPTH SET (MD)
31
3'
2260'
5 7282'
LINER RECORD
BOTTOM (MD)
basing
HOLE SIZE
17-1"
12-4"
8-3/4"
CEMCNTINC RECORD
472 cf Class B Portland
1665 cf 65:35 Pozzolanic,
A Ideal
236 cf Class B Portland,
SACKS CEMENT*
•
SCREEN (MD)
30.
SIZE
Cast i ro
Retri eva
AMOUNT PULLED
319 cf Class
271 cf Class
Tt.'BING RECORD COV
DEPTH SET (MD)
i Bridqepluq
Die br'idaepluq
PACKER SET (MD)
5745'
6690'
31. PERFORATION RECORD (Interval, lite and number)
6573'-6582', 6610'-6616', 6646'-6656',
4 jspf, .50", 100 holes
6700'-6710', 4 jspf, .50", 40 holes
32.
ACID. SHOT. FRACTURE. CEMENT SQUEEZE. ETC.
DEPTH INTERVAL (MD)
7122'-7260'
6880'-6888'
6760'-6772'
6700'-6710'
AMOUNT AND KIND OT MATERIAL 1'SED
59 cf Class 3 cemeni
59 cf Class B neat
5000 gal 15£HCL
5000 gal 15J HCL
PRODrCTION
DAT! riRST PRODUCTION
9-16-85
DATE or TIIT
9-17-85
PLOW. TUIINQ FUSS.
•>lo tubina
PRODUCTION METHOD (Flowing, gat lift, pumping — lize and type of pump}
Flow! ng
HOURS TESTED
24 hrs.
CASINO PRESSL'RC
760 D<^in
CHOKE SIZE
32/64
TAl.Cri.ATED
24-not-R RATC
PROO'N. FOR OIL BBL. OAS — MCK. W
TEST PERIOD I
*• 1 448 2913
Oil.- — RBI..
448
34. DISPOSITIAN or OAS (Sold, tiled for futl, rented, etc.)
WELL STATUS (Producing or
lAu<-in)
Shut-in
ITER BBL.
0
GAS MCr. WATKR--HBL.
2913 0
: TEST WIT.NE
UAS-OIL RATIO
6502
OIL ORAVITT-AP1 ( CORR. )
45°
.1310 BT
To be vented
35. LIBT OF ATTACHMENTS
N'"> no
38. I berrbr certlfj
SIGNED
ind atcachpd Information li complete aud correct *• determined from all avallabk record* ^
TITLE Admin. Supervisor
DATE 9-18-85
-*(5«t Initruciioni and Spac*i-fer Ad^itiamjl Doto-on
Tide 18 U.S.C. Section 1001, makes it * crime for any PefS°f'J«ttSiitydy and willfully to make to any depart;j»«nt(TJr agency of the
United Statos any false, fictitious or fraudulent statements cM*flltfl?ffattons as to any matter within us jurisdiction.
-------
J7.
SUMMARY OF POROUS ZONES: (Show all important zones of porosity and contents thereof; cored intervals; and all
drill-slerr,, tcslb, including depth interval tested, cushion used, time tool open, flowing and shut-in pressures, and
recoveries):
KORMATION
•Ian
ICJ 1
DaH
(~O c.
^_U ;3
ota
onr i son
nljrada
i rjgate
hi
ut
n I e
er
1 enmosa
1 snjay
) eaert Creek
k^
h
Jarker Creek
' i nkerton
1ol
. ea
5
c*
c
as Shale
dvi I le
[
)
i
TOP
o u r f ace
868
1046
2128
2192
2862
4136
5523
6248
6377
6450
6730
6890
7044
7136
BOTTOM
1046
2128
2192
2862
4136
5523
6248
6377
6450
6730
6890
7044
7136
TD
DESCRIPTION, CONTENTS, ETC.
i
1
i
38. GEOLOGIC MARKERS
NAME
'•
TOP
MEAS. DEPTH
TRUE
VERT. DEPTH
-------
STATE OF NEW MEXICO
ENERGY *»o MINERALS DEPARTMENT
•«. •• •***«• »«««**«•
Olf'«l«t/f IO«
• eVMf A f« ^
\;
W.i.O.4.
LAMO orncv
Ofi.
« Aft
0* CM A TO«
rMOttATtOM O***CC
—
t-
^--
-*-f
'^
f. *
\'\
\
•*"*"
1\
:^\
OIL CONSERVATION DIVISION
P. O. OOX 2088
FE. NEW MEXICO 87501
I.
QUEST FOR ALLOWABLE
l~J AND
TRANSPORT OIL AND NATURAL GAS
Form C-104
fl«»l««d 10-01-78
Form*! 06-01-U
Amoco Production Company
f change of ownrnhip C've nen«
ind tddrett of previoua owner
I. DESCRIPTION OF WELL AND LEASE
L.o.. Nam.
USG Section 18
43
Hogbark Ppnn
Stot*« r»d«roi or F«« i , .
1 Indian •_
l_»o» No.
l-89-INn-
Location
Unit Letter F_
58
1 *5fln Feet From The 'M^ ,.4
Lin* ol Section 18
To-n.hip 7QN
. Line and . 1760
16W
Feet Tfom The W<=
NUPM-
U. DESIGN'ATIOX OF TRANSPORTER OF OIL AND NATURAL GAS
•Con"** e./ Auihorlltet Tf«i:« pillar of CU ^ ;
Permian Corporation
or Cor.oensot* i_ ]
?ar«i* (Gtvt aadreiM to u/AicA approved copy o^ tAi/ form u »o 6t trnt)
P. Q. Rnv 1707 Fa-mi „„+,.„ NM 87401
em« o( Authority Tron»portcr of Caitinchead Co* 1 ) or Dry Ca*
To be vented
Addr«*& fCtvf addrett 10 u*Aic~A approtPe'd~f'oi?y of rAi'j /arm u 10 &r gent)
f *•*!! produc«« oil or liquid**
[v* location of lank*.
e. |Twp. | R,..
18 .'29N ! IfiW
qa> ociual.y connected? ( When
(hi* production 1> commingled with that from «ny other lose or pool, (ive commingling order number:
DTE: Complete Parts IV and V on reverse iide if necessary.
. CERTIFICATE OF COMPLIANCE
rceby certify that (he rulei and regulation* of (he Oil Conservation Division have
n complied with and (hat die information given a cruc and complete to (he b«i of
knowledge and belief.
,_Admin. Supervisor
(Tttl.l
9-19-85
OIL CONSERVATION DIVISION
I • V «.
*»-
BY.
TITLE
PFPIITY Oil K GAS INSPECTOR. DIST.
ThU form it to b« filed Ln compllinc* with MULC 1104.
If (hi* It • f«qu»«t for sllowftbl* for t n*wly drilled or d««p<-n-'
well, (hit form tnuit b-« «ccomp«nl»d by t (tbuUdon of the dsvi.ti^..
tettt taken on the well In tccordtnce vlth nuLC 111.
All.tectloat of thi* form mutt be filled out completely for »llo-~
tble on new end recoaiplet»d wellt.
Fill out only Sectlont I. II. III. end VI for chtnfee of owner.
well neme or number, a* (reneponer. or other tuch chenfe of condition.
Separate Form* C-10-4 mutt be Hied for each pool In multiply
romoleted wellt.
C-731
-------
Form C-104
H«r»Md 10fli.li
Fomul 05-01.43
Fig* 2
Cast Iron Bridgeplug set at 6745'
Retrievable Bridgeplug set at 6690'
fV. COMPLETION DATA
Designate Type
J Oil W.U ' Cos W«li ' N.w W«ll ' W«ko».r ' O««p«n J Plu — &o4o ' oc:ro , u / uu u / i u ^ .^ £> » -.5
L^J 3
O«plh Cailng Sho* "~
7283'
TUBING, CASING, AND CEMENTING RECORD
MOLE SIZE
17-4"
1 2 i"
R-7/4"
?-'
CASING & TUQING SIZE
13-3/8", 48#. H40
Q-S/fl", 3fi#. K55
7". 23#. 26#, K55
'& F-b-pgj^gg^ U-Uj 1
J L *0— ' ' " --01'1 ^
DEPTH SET
313'
2260'
7282'
gay £,£*> \ ,
SACKS CEMENT
472 cf
1984 cf
1321 cf
TEST DATA AND REQUEST FOR ALLOWABLE (T**t »i<«i i« o/i" r«i i, v»h « P'-/ i X«'n\ • -»«^«*— ' «rwwf^— — i
i— .T
c--"-— «"—»->
Gfffrity si Conaeneai*
CKok* £ls*
C-732
-------
UNITED STATES ..X«-.T .* i...-....-.™
<•• ,,-,-.!.., DEPARTMENT OF THE INTERIOR
Hum At/ or LAND M/^M^;I MI in
SUNDRY .„.._„, .,,.., --„_-....
J-^n r^ "vT* •* \ • " • .-t--3*. \ \ \ '
• t • •..- tfcu '-L*k«*T.?'-»«-.l..^ji VMii,**-r.. 4*Yrt»\^ l>1'
^-^35-
uw"" S^'v'" "*"0,VD^ '^'Vxtor,
501 Airport Drive,_Farmington,.N M ^87401 ' "^Soupcj^r
"iW.Viuo i» «ctL (K»piii"l II Wl.. | <
*""""" 1500' ife X 1760' FWL
I 4. rcciiir *»O.
KOTIC*
»*r«« ABor-orr
It. cuiT.no>-. (Sbo- -krti.r «r. «r. c«. ctc.1
5176' GR
lk,.l<,.| llu.v.u f»u. |rMM..|l| IS
-'"'-I'." Al">"i II. l';xS
I-89-IND-58
« «r **wi * • 41 u, -,
Navajo Tribe
r.
USG Section 18
43
10. ricia .no root., o. «IU><»T
Hogback Penn/Leadville WC
•QBVMT o* &A44
SE/NW Sec 18, T29N, R16W
12. COO»TI o
San Juan
11. «TATC
New Mexico
Appropriate BOB To Indi'coic Nature of Notice, Report, or OtKer Data
rrn. o* *t.Te«
WVLTIPI.K cox
TKC4TMCHT
KJiPAIRIMO
• noorina o* »ciotiiK« , , ^
(o.hen Additional-Completion
(NoTt : Report m«lti W ••ICIpl* coeooltUoo «o Well
Coxplrdo* «r Rfc»tap<«tlo« Report .ad Log t«rm.)
rl/ nil* ill pTdn'iil 4rl.ll.. old -\*r pertlarof 4«(a°« peril-
Moved in and rigged up service unit on 10-3-85. Set retrievable bridgeplug at
6520' and dumped 1200/J sand on top. Perforated the following intervals:
6400'-6410', 4 jspf, .50" in diameter, for a total of 40 holes. Pumped interval
6400'-6410' with 5000 gal HCL acid and displaced with-38 bbl 27, KCL water.
Perforated the following intervals: 6378'-6388', 6434'-6450', 4 jspf, .50"
in diameter, for a total of 104 holes. Set packer at 6357'. Unset packer at
6357' and reset packer at 6293'. Squeezed interval 6378'-6450' with 177 cu. ft.
Class B. Unset packer to 6229'. Drilled~cement~to"6450'." tagged" sand at
6490' and cleaned out to top of bridgeplug. Pressure tested cement squeeze to
1000 psi. Released bridgeplug set at 6520' and reset packer to 6531'.
Released the rig on 10-24-85.
BEIF
NOV081985
OIL CON. D/V
DIST. 3
NOV 0 7 1985
TITLr
Or APPROVAL. IT AKT:
MKtA
*S«« Ifnttvctiont
C-733
BY....-..
^» U.S.C. Scclion 1001. m«ktl il . crime lot .n r pcr.on
•".!<* lo mny
of th<
-------
r i .' i < .*> If'lTFD STATES SI'MUIT IN Tv.\\'\.\y\-r."
,r "-•:/'>' .iu> CE"V\RT,V;f.,%JT OF THE INTERIOR i-'/.'/I.-ti"."""'^?^"'
ni;,\M"Aij of I. AMD MAMAT.CMFNT ./
Lij.'ORY NOTICES AMD REPORTS ON V, ill. 3^'? j -
U«» "APPLICATION KOK rF.HHIT--" for « ipirr 17 Srlav.) !. . ' ; ^A \ ».-"". •' U _ ". — >— ~ •»_''' '. '
At •urr«ir» \ ^ 1 ^-l^-—"1 "~" I'll p
15001 FNL x 17601 FWL|lJ; ^^-v^-^^j \;|\\
S'l"?^1 (fR*^-^'
(VI(t»:«-( It ir. «U No. |(
|-" v; iff; A'i»-us( ,\ I t
[-H9 -JI.TJ-58
N;iv,-ijo Tribe
USG Section 1
9. WBU. |>O.
43
KM. ni i«,
'MS
8
10. rl«LO »«D f-OOL, 01 WIU>C»T
Hogback Penn/Leadville
11. «*C^ T, I, X, OI KI.X. AKQ
• CXTBT OR AAJA
SE/NW Sec 18 , T29N, Rlj|
12. COO»TT OK TA^tlH IS. f
San Juan New
riTK
Mexico
l*' Checlc Appropfiafc Box To Indicaie Nature pf ,Nofic«,"R«portr Of Otfi*f Data
t*cnric« or I^TKHTION TO : •c»-i*qcmnT KJLTOKT or;
SHOOT Ot iCIMX» a«4NOOH* •ftOOTIHO OK ACIOtXIWa
UFAIIJHO WILL
ALTTCtlXfi CASIXO
• CPAIC WILL CHANCE rtiNs (Ot*>fr)
.o,»,r, Additional Completion X__ ^^i^^^^^^^^f.^.^
—
unnc r«iru!icD o« coMrutTio orcuno.xr (Clfailj ilatr all p<-r(ln^nl drlill.. «nd flrr p«rtlaral d«t«. laeludlaf r.rtm«t«l (Ute of iUrtlot tor
propowri work. If •* Lbi« work.) •
Amoco Production Co. requests to further complete the subject
well according to the attached procedure.
Verbally approved by Jim Lovato on 10-4-85.
OCT151985
OIL CON. DIV.
DIST. 3
tyjjgnal Signed: STEPHEN w
,- - Jtft'X MANAGER
•S. 1*^- R SJ ' r«W«NbTON RESOURCE'
>•« Inttrucfiont on KcrcrM >id«
-i -: - ——_ IVMQCC-
tl* 18 U.S.C. Srclion 1001. mjkri ,( j cnme for any perjon tno^mRl)- «»d ArllTullv to make to »ny dcp.rtmrnr or «Rcncy o( the
ulro i«irs .«)• f»lic, .'iclilioul 01 frsuJulrnl tlitcmrnli or rr pr r» rnl itioni •» to «ny matter within ill jurisdiction.
-------
f£7.m£?-|98j> — UNITED STATES ?#DHMITJ.7r",I..LTT
(Former.r, ,_!.„, DEPARTMENT OF THE INTERIOR "'«•«"> ^ r
BUREAU OF LAND MANAGEMENT *
SUNDR
life* not (U* Ihla ror«
1.
»"• pi «•»• r~i
"ILL l^J W«LL 1 1
Amnrn Prnrlnrt
Y NOTICES "AND REPORTS ON WELLS
-Arri/CATiON FOR erpwi-Cf-^^l^-^Ktrv
OT"" IS' 'I r~:f^T
ion Comnanv r -.'A _ — ^~
I. Aooazaa or oraaAtoa <^j- - (^O"> C£RV.
501 Airport Drive Farm! ngton,"NM 8?4€r
See «l«n ipaer 17 below.)
At •urfaee
-*«r'';>1,g;"pl
^DM
-u- jy
1 ' -~^ •" —
f£.*A r^^*
lo tail work.) •
The subject well was spud with a 17-i" bit rather than a 12-i" bit as previously
reported. The rest of the casing and cement report is correct.
SEP20
OIL CON. DiV;
DIST. 3
TITI.K Admin. Sup.erv.isor . PA.T" Q-1Q-R5 _
tilt tpACf for KrderAl or
I'ROVFl) BT
NDITIONS OF APPROTAU IT ANT:
TITLE
DAT*
*S«« Initrwdion* on RCVCTM Si
I 8 U.S.C. Section 1001. mak
Siller tny («!»<;. :ic!ilinui
_ .
vcin R llfull v to make to any department or a Kency...ai--Vn'
....... "
-------
UNITED STATES SUD>"T IN w™ A™;,
DEPARTMENT OF THE INTERIOR
BUREAU OF LAND MANAGEMENT
WELL COMPLETION OR RECOMPLETION REPORT
-~" "a? -HH
b. TYPE OF COMPLETION:
xr.w f—I »"iiK f—I I»KKI'
WKI.I. I y tn KR I I rx
OIl-CONJWV.)--.-
___
4. IAI'ATION or HKI.L (Keaorrjfcatian clearly and
A"urf"<
;;<-.,-'-
At top prod. InterTtl reported below
any State
At tool depth
Same
o
bame
CEI
SEP* 19 1985
OATC IS.1TCD
*. J*EK>1 IT i*l». U* * *• t*i'i« i
BUREAU OF UNO MANAGEMENr
Form approved.
Budget Bureau No. 1004-0111
Expire* August 31, 1985
I-09-IND-58
(1. ir IMMAN.~*l.l.ilTTKI OH
'T.'lTTlf
USG Section 18
tl. WIl.l. NO.
43
10. PIELD AND POOL. Ot WILDCAT
Hogback Penn
Fl. »«•.. T.. R., II., OK DLUCK AS
OK AREA
SE/NW Sec 18. T29N.
12. COCSTT OB
PARISH
San Juan
13. 9TATE
NM
IS.
20.
PATS srrotito
7-13-35
16. DATE T.O. REACHED
8-18-85
TOTAL DCTTH. VO A TYQ
7283'
21. FLUO.
17. I'ATB COM PL. (
9-16-85
1ACK T.O.. MD *
7271'
TVO
22.
tfttill},
ir >i
HOW
Si
-('(Tprod.)
IS. ELEVATIONS
518
I.TIPI.E COMPt..
MAM*
ng le
j.i. i
19. ELEV. CA3INGHC1D
5176' GR
\Ti:R»*ir«
g»it 1 1 t.t;i» MT
CABLE TOOU
I O-TD
24. rnoDL'ciNC iNTr.RTAi.(a). or THIS COMTLET
6573'-6656' Penn
FDC-CNL; 01 L-GR-SP-CAL; D
ION— TOP. BOTTOM. MAME (MO AND TVO)«
25. via oiRicTimii
3 CIV 1 1 MADE
Yes
27. WAS WILL C01ID
i pmeter ' NO
CASING RECORD iKtport all firings act in %crll)
e A.I INC sue
13-3/8"
9-5/8"
WEIGHT. L«./rr.
48,?, H40
36#, K55
231, 261, K5E 7282
DEPTH SET (MD)
313
2260'
HOLE SIEC
12-4"
8-3/4"
CCMr\TIN« RECORD
472 cf Class B Portland
1665 cf 65:35 Pozzolanic,
A Ideal
236 cf Class B Portland,
AMOUNT Pt'UID
319 cf Class
f71 cf Classi
LINER RECORD
TOP (HO)
Flowing "hrough 7"
BOTTOM (MD)
as i ng
31. rcftroftATius *CCOED (Interval. HIT and number)
6573'-6582', 6610'-6616', 6646'-6656',
4 jspf, .50", 100 holes
6700'-6710'f 4 jspf, .50", 40 holes
(MD)
30.
TUBING RECORD
(We
nr.i'TH air (MO)
Cast I-on Bri dqepIuq
_R_etr; svable brldqepluq
PACKEX 3" (ml
5745'
6690'
S2.
ACID. SHOT. FRACTURE. CEMENT SQUEEZE. ETC.
DEPTH INTERVAL (Up)
AMOUNT AND KIND Of MATI1IAL I'3IO
7122'-7260'
6880'-6888'
59 cf Class B cement
•• 59 cf Class B. neat
676Q'-6772' ,5000 gal 15% HCL
670Q'-6710' ! 5000 gal 15% HCL
PRODCCTION
DATB riRBT PRODUCTION PRODUCTION METHOD ( FfoiCinp, gat lift, pumpmff— .Vre and type o/ pum p ) W«t
9-16-85 Flowing Sh
DiTC OF TC8T
9-17-85
NO -tub i pa
HOI RS TESTED
24 hrs.
CAfllNC PRCSSt HE
760_p_s_iq
CHOKE SIZE
32/64
H-noi-R RATE
PROD'S. FOR 0
TEST PERIOD
Oil. --BBI..
448
.14- plKro^iTld.v or CAS (50ftf, u«rtf /ur fuel, rrntrtt, etc.)
IL BBL.
448
CAS — MCP.
2913
IAS- '.M'K WATER — B
29 1 3 1 0
« «TI.R" BBL.
o
TEST WITN
L STATUS (Producing or
Ky(-tn)
jt-in
8L. (iAS^JIL RATIO
6502 _
OIL CRAVITT-API (COH.I
45? -
ES.1ID BT
Sin.VED
ind iltachrd Infurmndoo li complete and correct •• cjMrrm!i"-'l fr..m nil ivtlUble recordl iJOO
TITLE
*(S«t Initructioni and Spaces fcr AdQtTiZ&S Data on Revene Side)
Tule IS U S.C. Section 1001. rrakfs it a crime for in\
Uni'^d T-'a:, « wny false, fictitious or fraudulent stattr
Ily and wil!(u"v :c r,.
t ftf. ons - s to anj ••.:
• :*.e 10 iny depinmenl or agency
"IT -A.-:ihm its jurisdiction.
-------
37. SUMMARY OF POROUS ZONES: (Show all Important zones of porosity and contents thereof; cored intervals; and nil
dril 1-Rlrm, lost*., infludnii; depth interval tested, cushion used, lime tuol open, flowing und shul-in pressures, and
recovcues):
' FORMATION
Man cos
Dakot~a
M orri son
: ntrada
V i ngate
C hi nle
C utler
H er,mosa
1 smay
D esert Creek
<\ kah
3 anker Creek
3 i nkerton
•1olas Shale
. eadvi I I e
i
i
Q
f
-J
i ni
*>f
-g
.
i
i
1
!
i
-
1
i
1
TOP
Sur face
868
1046
2128
2192
2862
4136
5523
6248
6377
6450
6730
6890
7044
7136
BOTTOM
1046
2128
2192
2862
4136
5523
6248
6377
6450
6730
6890
7044
7136
TO
DKSCKIPTION, CONTKNTS, ETC.
•
f
38. GEOLOGIC MARKERS ^v,
». \^
NAME
TOP
MEAS. DEPTH
(
TRUE
VERT. DEPTH
-•
-
1
-------
UNITED STATES
MENTOF THE IN
BUREAU OF LAND MANAGEMENT
eorm 3160-S- •~IH
Err*",-"?, DEPARTMENT OF THE INTERIOR --
•UDMIT in
SUNDRY NOTICES AND REPORTS ON WELLS
not tbi* work.) •
Moved in and rigged up service unit on 8-26-85. Total depth of the we I h is 7283'.
Plugback depth is 7271'. Pressure tested production casing to 3500 psi for 30 minutes.
Perforated the following intervals: 7 122 '-7 128', 721 8' -7234', 7252 '-7260', 4 jspf,
.44" in diameter, for a total of 120 holes. Squeezed interval 7122'-7260' with
59 cu. ft. Class B cement. Perforated the following intervals: 6880 '-6888',
4 jspf, .44" in diameter, for a total of 32 holes. Squeezed interval 6880 '-6888',
with 59 cu. ft. Class B Neat cement. Perforated the following intervals: 6760'-6772',
4 jspf, .50" in diameter, for a total of 48 holes. Acidized interval 6760 '-6772'
with 5000 gal 15$ HCL. Set cast iron bridgeplug at 6745'. Perforated the following
intervals: 6700'-6710', 4 jspf, .50" in diameter, for a total of 40 holes. Acidized
interval 6700'-6710' with 5000 gal }5% HCL. Set retrievable bridgeplug at 6690'.
Perforated the following intervals: 6573'-6582', 6610'-6616', 6646'-6656T, 4 jspf,
.50" in diameter, for a total of 100 holes. The well is flowing through the 7" casing.
As soon as the pressure goes down, tubing will be landed in the hole and a subsequent
sundry will be submitted.
crrtl/r
I'HOVKI) BT
and correct
Admi n . Superv f sor
0157.,$™ -?=Ja-
or .St*t* offlcr
NOITIONS Or APCRO7AL. lr ANT :
TITLE
Vj'*>'-
DATI
8 U.S.C. Section 1001, mai,
r-T^fr- -~ BY -.:--
it a crime for any person knovr,n C[\J jyj(jj^j^rul I v (o make to any department or ageTicy
of (he
-------
Farm JI60-S
(Nliveilllirr ,l<)83)
(Kormerrv ^J-3.1
SUBMIT IN TRII'MCATK-
(Olner In. (ruction, on r»-
DEPARTMENT OF THE INTERIOR "'-•"">
IIMITFO STATFS
UINIIC.U O I « I C.J
MENT OF THE IN
BUREAU OF LAND MANAGEMENT
SUNDRY NOTICES AND REPORTS ON WELLS
ll>" not uie tbU form for proposal, to drill or to 4e*pea or plu< back to a different reiertolr.
U«e "APPLICATION FOK PF.KMIT—" (or .ueh propouJi.)
L£89-_IND-58
«/ir IHUIAH.'AI.LOTTII
OIL r-j c»a (—]
• CLL l_A WCLL LJ
2. NAM* or orctATOt
Amoco Production Co.
1. Anoacaa or or-HATOa
501
IJI':ATIO* or WELL (Report location clearly and lu accordance with any State requlrementa.j
See aHn llpace 17 below.)
At turface
1500' FNL x 1760' FWL
RECEIVED
AUG271985
14 I'CKMIT NO
15. Cl£VATI4N9 (Sho« whBCT-orr
lltPAIR WELL
Tt.L 0* ALTtH CASINO I
JULTIfLi coMri.rre '
WATCS HHOT-orr
r«ACTt.'»t TXATUCNT
BROOTINC OK ACID121NO
(Other)
Spud & Set Casing
IIAMDONWINT*
(Nori: Report retain of moltlplc completion on WeJl
rumpletloo or Retouplttlon Report «od Loc form.)
IT i.ti.i.mnt i-norusco on CUMPLCTCU orenATiu.vr (Clearly state oil |wrllin-(it drtillK. ind ;lv» pertinent ditei. Including eitlmated d«te of lUrUnt 107
pronourd -orlc. If wrll u dirKtion«Jlr drilled. lire lubiurfice lot»n..ns and rarimirrd and true eertlcil depthl (or ill marker! and tone* perti-
nent to thi> work.) • .
Spud a 12-1/4" hole at 1100 hrs on 7-18-85. Drilled to 313'. Set 13-3/8",
A8#, H40 casing at 313' and cemented with 472 cu. ft. Class B Portland.
Circulated cement to surface. Pressure tested casing to 1000 psi for 30
minutes. Drilled a 12-1/4" hole to 2260'. Set 9-5/8", 36#, K55 casing
at2260'. Cemented with 1665 cu. ft. Pozzolanic 65:35 poz and tailed in
with 319 cu. ft. Class A Ideal. Circulated cement to surface. Drilled
an S-3/.'-' hc..e to r TD of 7283' en 3-18-^3. ? :(i ; , •,
1 hereby ctrtlf
AUG29 1385
OIL CON. DIV.
(Tbla ipac« for
^^ ^ ' \- wv>""y __ TITLK _Adm. Supervisor
BT
TITLE
CONDITIONS OF APPROVAL. IF AKT :
*S«« Inttructiont on R«v«rt« Side
1. makes it J crime for any person JAbWrVW
DATE
bbb
AREA'
le IR U.S.C. Sfttion 1001. mikes it j crime for any person brVW Jni^rlkijl 1 v to make (o any department or a
ilea Sialel -ny filsc, :'iclitiou* or fraudulent statements or representations •slo any matter wuhin its jurisdiction.
-------
WILSON
SERVICE COMPANY
432-2
TEMPERATURE SURVEY
WELL... 43 LEASE ...usa-^
COUNTY....San.Juan STATE....JSew.
SEC aa TWP jzffi.1. RGE M...
APPROX. TOP CEMENT.
Survey Begins at L001.. ._. _ Ft. Ends at.. ..._5.018.! Ft
Approx. Fill-Up _ Max. Temp
Log Measured From ..KB Run No. ..J.
Casing Size ' Casing Depth Diam of Hole Depth
7!:. from to _ _„_ fromQ_2/.41_. to
from to — _ _ _ _ from __ to
Date of Cementing £J19ZS5...._ _ TL-ae
Date of Survey _S^19,/S5_ Tims _i:3XLpa
Amount of Cement As..P.er..E.ep.o.i-.t; _ _„_._ .
Recorded by JEfednett Witnessed by.
C-740
-------
Form 3160-3
, (itovembor 1983)
UNITED STATES t,
SUBMIT IN TRIPLICATE
(Ulkrr liMininioai en
r«w.u,,
.
Budget Dure.u No. 10O4-0136
Ezpircs Aupjtt 3i_ 1995
0
»" ucrrtK-wvijtrc i ur i nt iNicmun
/j^^fQJS^ftf^j^AG EME NT
APPLICATION F0^PERMirTOAi^Rfri^
la. TiPEorwoaK (t^K. **Vfl/ Pft «,, }//
DEEPEN, OR PLUG BACK
p PLUG BACK D
SINOLS |—| MULTIPLE RJ1
tONB 1 1 IONS 1 1
2. NA«TB or orEtAToa^ft " " *-'-^ fife '^iQfiJ
Amoco Production-Go...
3. AOOBEaa or opEaAToa " ' •-..
501 Airport Drive, Farmington, N
•2
• M? 87401
4. LOCATION or WBLL (Report location clearl/ Bad la accordance wan any State requlreatDLt.* )
1500' FNL x 1760' FWR E C t I V E D
At proposed prod, sooe ' J^
same APR 0 1 i?c5
14. UIKTANCE ID HILCB AND DIBBCTION FSOM NBABBBT TOWN OB PO«T OFFICE*
23 miles west of Farmington Be^M^§Tr^^"°^'j°c.F. AREA
LOCATION TO X AlEET
raorsBTT o« L ABE LINE, rr. 860 '
(Alao to orart t drlf. unit Unr. If anyi
IS. DIBTANCC raox rtoroaco LOCATION*
TO MAKCJT w LL. OSILLINO. COM PLETEO. CDO ' C<->
oa ArruED roa. it TRW LSJUU. IT. JUU OO
DRII 1 !Nrt..nWJl4
14. NO. OP ACBSB IN UASE
4800
IB. mOPOBCD DEPTH
7239'
rirt«IO «t!TII«n(Tfm •--
J. LEAKS DaalUNATION AND BBalAL NO.
I-89-IND-58
a. ir INDIAN, ALLOTtEB OB TBiaB NAMB
Navajo Tribe
7. UNIT AOBBBHSNT NAHB
USG Section 18
8. WELL HO.
43
10. FIELD ANO POOL. OB WILDCAT
Hogback Penn/Leadvil
11. aac_ T.. a, M_ OB BLB.
^-7 ANO BUBTEI OB ABBA
'SE/NW Secl8,T29N,Rie
12. CODNTT OB PABIBH 13. BTATE
San Juan NM
TO THII WELL i r a-* A r\
l^0 Jrfr0740
20. BOTABI OB CABLE TOOL*
Rotary
«. SLBTATIONB (Show wbrthcT DF. RT. CR, .tc.) UKILLIPILi jjl 'tl(A i iui i o nuniu.MZ.OLi hKC
5176 ' GR SUBJECT TO COMPLIANCE WITH ATTACHED
"PCMCDAI nrrMnnrxrmTo ii
22. APPBOX. DATE WOBB: WILL BTAET*
As soon as permittee
JUIREMENTS
pROoEDsiNC.AND CMENTING PROGRAM
Inis actl°n is subject to administrative
•izc or HOLE
17-1/2"
12-1/4"
8-3/4"
•iu OP CABina
13-3/8"
9-5/8"
7"
WBICHT res poor
48#,H-40
36#,K-55
23#, 11-80
• ETTIXC DEPTH
200'
2240'
7239'
gUANTITT OP CEMENT
354 cu ft Class B
1057 cu ft Class B
1634 cu ft Class B
Amoco Production Co. proposes to drill the above well to further develop
the Hogback Penn-Leadville reservoirs. The well will be drilled to the
surface casing point using native mud. The well will then be drilled
to a TD with a low solids nondispersed mud system. Completion design will
be based on open hole logs. Copy of all logs will be filed upon
completion. Amoco's standard blowo.ut prevention will be employed; see
attached drawing for blowout preventer design. Upon completion the well
site will be cleaned and the reserve pit filled and leveled.
No H2S gas is expected to be encountered based on the drilling and
completion of the USG Section 18 #38.
«»OTI mrtrt Dcartim noroKD nooxM : If prapoul !• to drrp*n or pluc back, rl" d*ti on pmtnt prodncttT* tone tod propow-d new produrtlrt
If proton*! !• (o drill or d
dirrctlontllj. xlrv p+rftaeDt data oo •ubnurfact? I oca C tuna *nd
aod true vertical depth*. Glrv blowout
(Thu
or .Sl«tr officr
fe B E 8 f IS jfjjAS AMENDED
JUN1 7i:35
JUN 121985
cea
Oil
NMOCC
Inttructiofir On R«v«r»* Side
Title 18 U.S.C. Section 1001, makes it • crime for any person knowingly' atil willfully to make to any department or agency of the
M. MILLENBACH
AREA MANAGER
United Su
fraudulc
s to any matter within its jurisdiction.
-------
-STATE 'Cf N£W MEX1C3
OIL CONSERVATION DIVISION
P. O. BOX 2Q««
SANTA FE. NEW MEXICO 873OI '
All di»i~«.. ™u»< te /'•— c
""*""" AMOCO PRODUCTION COMPANY
Unll U^IIOT
F
Actual FUIOQV ^oct
1500
S^clloa
18
ition oi '*'«il«
f«-*4 fi^m thv
Zraund U«Y«| £J*r.
5176
h« «xi«r b«uid«l>< «f l*» 9>ctl««.
L«a»* •*«» NO. '
USG SECTION 13 43
To~nnup
29 N
NORTH „„.«,
Pmdueinq rornxnlaa
Penn-Lead villa
PooJ
Ho
Honq« C9»nir ~~
16 W San Juan
1760 tcvl from Ihs WEST tin.
(A/^C ^WlrtAcx^o^
1. Outline the acreage dedicated la the subject well by colored pencil or hacKure marks on the plat below.
2. If more than ana lease la dedicated to the well, outline tfach and identify the ownership thereof (both as to workitu
interest and royalty).
3. If more than one lease of different ownership is dedicated to the well, have the interests of all owners been consoli.
dated by communiiization, unitization, force-pooling, etc?
C3 Yes
Jfo If answer i» "yes** type of consolidation
If uswer is "no," Hat the owners and tract descriptions which have actually been consolidated. (Use reverse side of
this form if "»<-i»««-ny ^
No allowable will be assigned to the well until all interests have be«n consolidated (by comnnraitization, unitizatiixi,
| i
1 1
I
1
I1
1
1
1
"
CERTIFICATION
f Awwir C***>'r '*w/ **• in(ori**tl*n nr
tminmj h+rmi* !g frua ond eoMV^/vf» M tt»
. D. Shaw
Supervisor
Co
-------
)£ 1983) 1
^«rly 9-331) DEPARTN
BUREAI
JNITED STATES ?o^MITi "* TRIPUCAT»*
1ENT OF THE INTERIOR «». aid.,' ruc °" " ""
J OF LAND MANAGEMENT
SUNDRY NOTICES AND REPORTS ON WELLS
(Do not tut thla form for proponali (o drill or to dreprn or pluc back to a different reeerrolr.
UK "APPLICATION FOR PERMIT—" for iuch propoMUa.)
1.
OIL ^~~] CAB 1 1
WELL <-U WELL I_J OTHEB
2. NAME Or OrEBATOB
Amoco Production Co.
3. ADoaua or oraaATOE
501 Airport Drive, Farmington, N M 87401
4. LOCATION or WELL (Report location clc
See also ipacr 17 below.)
At turface
1500' FNL x 1760' F\
14. rXHMIT NO.
arlj and In accordance with an/ State requirement*. •
RECEIVED
MAY 13 1985
IS. BLEYAiiof«UI»c*>»he*fc«n.n«.BirJ o«w*lfc4 JE.ME.NT
cl -7,- .^ASMiNGrON Rlr SOU •*>.>: AREA
3J. / O «K
budget Bureau No. 1004-0135
Expires Auitust 31, 1985
ft. LEABB DEBIO.IATIOH AND BBEIAL no.
I-89-IND-58
4. ir H>DIAX. ALLOTTEE OE TIIBB KAKE
Navajo Tribal
7. OHrr AOBEEWBHT RAMS
8. r*aH oa LBABE MAKE
USG Section 18
9. WBU. »O.
43
10. riBLO AMD POOL, OE WILDCAT
Hogback Penn/Leadville
11. B*C_ T, *-. M, oa fix. AJTO
BUBVBT OB ABBA
12. COOUTT oa rAaiaa 13. BTATE
San Juan NM
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
WOTI
TEST WATia .IBOT-Orr
raACTuac TBIAT
a HOOT oa ACIDBB
aCFAlB WCU.
(other) Botton
ca o
r INTtMTIO* TO :
PT'LI. OK ALTF.K T%SI>0
UVLTIPLC COMfl.KTC
ABANDON*
CHANCE FLAN8
i Hole Location
z
—
X
10 ai
WATBE SHOT^rr
raAcrva* TMATHUTT
••OOTIHO OB ACIDUIKO
-------
..I', or \u-jj f/LXiCQ
t »'«.' Mi:;i.lUi.S (JtPABTMtHT
uii c-ON-jr.K v A I IOTJ Ui vr.,i(.
I'. O. UOX ZOMH
SANTA PC. NEW MCXICO U/'j"!
I""1 M
""'•"
IM,
^,»(ut(ir
Amoco Production Co.
V |r""
Is
1'
29N
Arluul ( i.-.l-i-j* l.oculi'.n of "*>ll:
1650 North 1
f^et from iKp lin* Win
CfOur.'i L,?»'rl (,!*»».
5176
I'fodijrtitq rwmallon F
Penn/Leadville H
u's*G Section 18 43
16W
760
Itct
Counlf
San Juan
West
from (h«* lln«*
oQg UnOeS« Ocdlcnu^d Acroogv; ^
ogback Penn/Leadville 160/40
]. Outline llic ucrcngc dcdicalcd lo ihc Hubject well by Colored pencil or Imchurc marls on die pliil liclow.
2. If inorr ihnn one Icnse it; d'-dicnlri) lo tlie well, outline cnclt nnd identify the ownership tlirrcnf (holli as to worlij
interest und royalty).
3. If more than one Icnse of different ownership is dedicated (o the well, hnvc the interests of all owners Leen consul
dnlrd by coiiimunifization. unilination, force-pooling, etc?
[ ) Yes | | No If nnswcr is "yes" type of consolidntion
If nnswcr is "no," list the owners and tract descriptions which hnve actually been consolid.ilitd. (Use reverse side»i
this form if necessary.) .
No allowable will he assigned to the well until all interests have been consolidated (by communitizntion, untti:ntioi,
forced-pooling, or otherwise) or until a non-standard unit, eliminating such interests, has been approved by the Divisln
-, •
i
1
1
I
1
1
1
>. j.
1
i
1
I
1
i
1
i N"
\J
ffjfSo^
^
u«i.
Sro/ a
1
1
I
1
1
1
l£tj JJ3 fo!* "
/fli v=r^ jg h $& fi*
W UI V tig
•1 J/y>.
o/£ Co;v /3S5
j ^/sr.3D/Vfv
R E C E | V E D
MAY 13 '1985
BURtAU OF LANDiMANAGEMENT
FARWNGTON RESOURCE AREA
1
1
1
1
SU* Hole Z.OC4/)0^
CCRTIFICATION
1 h«rfbjr certify fhof fn« /nforfnqfton con<
N plot ~ot ploiltJ t">" '"W
noln of oclvot »u«»ry« mnrf» l>r "" "
undrf mr '•« '"""
l> llu« onrf cornet n> f*** I"*1 •' "^
&no«-frf^g« ono* 6«/»«/.
•
u«. I'*. I t..t*«.l i'utvrj.'i
•-.--. n -—-.,
m iw*
-------
Sampling Report
Investigation of Cities Service Oil and Gas Corporation's
State E Lease
Lea County, New Mexico
June 27, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Permian Basin production sites developed by the
New Mexico Oil Conservation Division at the request of EPA. The
list was transmitted via telephone to the EPA contractor on June
10, 1986. Site selection from this list took place during the
telephone conversation.
New Mexico state officials preferred to list the possible sample
sites as shown below. The EPA contractor had no interest in the
manner the particular sites were listed (by site name, location,
operator, permit number, API number, etc.) as long as the site
could be identified in detail upon selection. Thus, the EPA
contractor had minimal information which kept to a minimum the
amount of bias. No other information was known about the sites
on the list at the time of selection. Detailed information was
obtained only after selection of primary and back-up sites. The
list consisted of five production sites in southeast New Mexico:
1. East Hobbs - San Andreas
2. Denton - Devonian
3. Eunice - San Andreas
4. Lovington - Abo
5. Eunice Monument - GBSA
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
No. 5 on the above list (Eunice Monument - GBSA) was selected as
the primary sample site. The New Mexico Oil Conservation
Division conducted a reconnaissance visit to the primary site.
The reconnaissance visit confirmed the appropriateness and
availability of the site for sampling on June 27, 1986.
Therefore, no back-up site was required.
Site Location
Cities Service Oil and Gas Corporation's State E Lease is located
southwest of Hobbs, approximately 2 miles west of Monument, New
Mexico. Figure 1 is a map locating the production site.
C-745
-------
• ! ;' "".'• !i' c-. f " <
" „
""',
...
N
^
"'—...
1
4
f
" J
t
\ i
r .
IM*
?
'
""'" " 1
; » • 1
• • f
1
• . I ',
' ' 1 •' ' • "
^'
A. '-""
'
* f,,'*"* '•*
r, f •*"'."'?: ?*.r*" "-*
. J- *
tltl 4
/ .
'
' '
.
Figure 1. Location of Cities Service State E Lease,
Lea County, New Mexico
C-746
-------
The site is operated by Cities Service, whose mailing address and
telephone number are:
PO Box 1919
Midland, TX 79702
915-685-5600
Contact: Elmer Startz, Regional Operations
Manager
Attendees
Sampling of Cities Service State E Lease was performed by CENTEC
Corporation personnel on June 27, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
Andy Procko, Engineering
Manager, Acting Technician
EPA Representative:
State Representatives:
Operator Representative:
Susan de Nagy, Office of Water,
Project Officer
Dave Boyer, NM Oil Conservation
Division
Eddie Seay, NM Oil Conservation
Division
Jerry Sexton, NM Oil
Conservation Division
Joe Gibson, Asst. Production
Foreman
American Petroleum
Institute Representative:
•
Site Description
Bill Freeman, Observer
Cities Service State E Lease is located within the Permian Basin
in rural flatland. The depth to groundwater is less than 25
feet, and the nearest surface water is over 2 miles away. There
is one drinking water well within a 1-mile radius of this site.
The soil in this area is mostly sandy rock. The climate at this
site location is net evaporation.
This site consists of four actively producing oil wells with a
total production of 150 bbl/day and a gas well with production of
less than 60,000 SCF per day- Production at this site is sour.
The average well depth is 5000 feet. The wells produce a total
of 700-800 bbl of water per day. The wells are producing using
natural drive.
Figure 2 is a schematic diagram of the production facility. The
site consists of a 135 bbl free water knockout tank (shown in
Photos 1 and 2 in Attachment A), a 100 bbl heater-treater (shown
in Photos 3 and 4 along with the free water knockout tank), and
three 500 bbl oil stock tanks. The free water knockout and stock
C-747
-------
o
oo
M
Figure 2.
-------
tanks are cleaned every 5 years. The heater treater is cleaned
every 1-2 years. The heater treater was cleaned last sometime
between June 1985 and June 1986. No biocides are used at this
facility.
Disposal Practices
A scale inhibitor (NALCO-VISCO-953) is added to the brine prior
to disposal. Brine is disposed by reinjection by Rice
Engineering Services. Operation and maintenance costs range
between $0.02-0.25 per barrel of produced water.
Permits
This facility operates under Permit No. 30-19-37 issued by the NM
Oil Conservation Division. The original Notice of Intention to
Drill for the five wells on the lease is shown in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Location
The sample collected at Cities Service State E Lease consisted of
one liquid sample. The sample was collected at a valve at the
bottom of the free water knockout tank. The sample team
requested permission to collect the liquid sample at a point in
the exit water line containing the combined water flow lines from
the heater treater and the free water knockout tanks. This was
not permitted by the onsite representatives.
Sampling Methods and Equipment
At the direction of the EPA Project Officer, the sample was
collected by filling the sample bottle directly from the valve at
the base of the free water knockout tank. Hydrogen sulfide
concentration was less than 0.5 ppm according to Draeger tube
tests. Tests for pH of the produced water were conducted onsite
after the completion of sampling. Test results gave a pH value
of 8.
C-749
-------
C-750
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-751
-------
Photo 1. Free water knock-out tank, sample point
coI IectI on
Photo 2. Free water knock-out tank, sample point
coI I ect I on
-------
ATTACHMENT B: PERMITS
C-753
-------
C-754
-------
FOr.M 'M'H
NE1 IEX1CO OIL CONSERVATION COM? 'SION
Santa Fe, N«w Mexico
NOTICE OF INTENTION TO DRILL
NV,;' . inuot ','_• given to the Oil Conservation Commission or its proper agent ai ! approval ablated before drtUi: -
h-•-.... li changes in the proposed plan are considered advisable, a copy of thi. notice stowing such change will be
M 'M:T.'-.: :,•> the sender. Submit this notice in triplicate. One copy will be returned following af proval. Set addi-.jual in-
.s:;v.L"ion? in Rules and Regulations of the Commission.
11_._1.956
Place
.
uate
OIL CONSERVATION COMMISSION.
S.-::ta. ;'e. N'sw Mexico. ,
Gec:!e;nen:
You are hereby notified that it is our intention to con,jience the drilling of a well to b- know- as
Unp 1 ra 3as .. & Znal ...0 o. S.t.01..9-
Company or Operator Lease
of sec. 50 .. , T 19 , R-~3.7 N. M. P. M.. .._JiQnnia.en..t Field Laa. county.
The well is 19.8Q-..feet (N.) (.'..) of the -SOUttl line ind 19SO - feet
N*.
(K.)
of
of ....
(Give location from section or other legal subdivision lines. Cross >.at wrong directions.)
If state land the oil and gas lease is Xo Assignment No._
If patented land the owner is —
Address —
If government land the permittee is
Address
The lessee is
Address
£r.rtl.a3.7.illB.w.fl k 1
LOCATE WELL CORRECTLY
propose
to drill well with drilling equipment as follows :-J}&LdJf.y. — Zc.C-L5...
The status of a bond for this well in confonnance with Rule 39 of the General Rules and Regulations of the Commission
is as follows: _ .O.^JL«
AVe propose to use the following strings of casing and to land or cement them as indicated:
Size of
Hole
Size of
Casing
T2^-"
9 5/8"
7"
Weight Per Foot
50
40
24
New or
Second Hand
Bew
liew
Hew
i
1 Depth
1 SCO1
2400'
5800'
I ' Landed or
Cemented
i
Cenert
C GtHG^l u
i Cement
! Sacki
1 Cement
; 150
: 700
' 150
If changes in the above plan become advisable we will notify you before cementing or landing casing. We estimate that
the first productive oil or gas sand should occur at a depth of about S900-^ feet.
Additional information:
Approved
e>:cept as follows:
OIL CONSERVATION COMMISSION,
Title
Sincerely yours,
position Div- i sicn-S-upl-t-, -
Send communication regarding \vell to
Name .._...J>.r_.-T)..-Bo<3ie -
Ho'b'bSjHev; Uexico
-------
C"101
NE- MEXICO OIL CONSERVATION COM" 3SION
Santa F«, N-ew Mexico
NOTICE OF INTENTION TO DRILL
.-t;-.:cc;ons in Rules and Regulations of the Commission.
Place D""
CIL CONSERVATION COMMISSION,
Sjuta !•"«, New Mexico. i
G^ntleEben:
You are hereby notified that it is our intention to commence the drilling of a well to be Icnown as
--znir 3. .oil. and 3
£0
it...
_3tate-S..
Lease
Companv or Operator Lease
19 „ £/_ N M p M liQ.nwfl.9nti-....
•Well N i .§
Field.
-ln_2L3Li±.
'*
^ Count),
The well is_.5s!.P. fist (N.) (ST.) of the APM''! line and.....2.3.lQ. ta,
(E.) (4.) of the_!§3*_-llne of __SeOtton_iQ=i9=S7
(Give location from section or other legal subdivision lines. Cross out wrong directions,]
If state land the oil and gas lease is No. Assignment No __
If patented land the owner is ._...
If government land the permittee is .
Address
The lessee Is
Addresg
LOCATE WELL CORRECTLY We propose to drill well with drilling equipment as follows: fi5_5&rj
The status of a bond for this well in confonnance with Rule 39 of the General Rules and Regulations of the Commission
is as follows: .!*._?. ~.? ,
We propose to use the following strings of casing and to land or cement them as indicated:
Size of
Hole
Size of
Caiing
Weight Per Foot
New
Second
or
Hand
Depth
Landed or j
Cemented 1
Stcki
Cement
95/8"
"
50
26
24
new
new
new
SOO
2500
5000
ca-nentedi 200
Cenentedj 700
Geasntedi 150
If chances in the above plan become advisable we will notify you before cementing or landing casing. We estimate that
the first productive oil or gas sand should occur at a depth of about A?Q.§.0 feet.
Additional Information:
Approved
except as follows:
... 19-
OIL
Title
x COMMISSION,
Sincerely yours,
3nmi
i IkfirJ,J5£ Co.,..
Compa'ny^or Operator
By
Position J
Send communication regarding -well to
Name o).».~..D-, -Bo Gi-Q
....Hobl?g..,....;i w...Ma:;ic.o_.
, AddLcs
-------
NE^ MEXICO OIL CONSERVATION COIF ^
Santa Fe, N«w Mexico
NOTICE OF INTENTION TO DRILL
N 'i ••: rr- is b« rivren to the Oil Conservation Commission or its proper agent and approval abtstned before dr.Hla?
'.it-4 \.-:>. It changes in the fTOpoaed plan are considered advisable, a copy of this notice showing such changes will b°
r*:u:-Tie-l fa the sender. Submit this notice in triplicate. One copy will be returned following approval. Sea additional in-
structors .n Rules and Regulations of the Commission.
Place Date
OIF. CONSERVATION COMMISSION,
Santa Fe. New Mexico. ,
Gentlemen:
You are hereby notified that It is our intention to commence the drilling of a well to be known as
of Sec. 50 .......... ,T.
N.
011.& BefInin&....Co, s_tate-3
Company or Operator Lease
37
Well No_...
In
19.
R _«;_<_ , x. M. P. M., ^.r.H!£: ?f±^
The well is.
(E.) (W.) of the
_feet (N.) fS.) of the ..?..!
Jeat
,. Field ^?r_ County.
line and _§.6.P. feet
of Sao. 50-19-57
(Give location from section or other legal subdivision lines. Cross out -wrong directions.)
If state land the oil and gas lease is No.._ . . Assignment No
If patented land the owner is — _
Addr ess • -
If government land the permittee is
Address . —
The lessee is _SPjir9 Oil and Refining Co*
Address
AREA 640 ACRES
LOCATE WELL CORRECTLY
We propose to drill veil with drilling equipment as follows: —
Botaxy (Tools
The status of a bond for this well In conformance with Rule 39 of the General Rules and Regulations of the Commission
Orr
._ _..__ •£>•• ._.. __.
We propose to u^e the following strings of casing and to land or cement them as
Si» of size of Wei nt pap Foot
Hole Caeing *
12V 1 50
9 5/8" | 40
i 7" 1 24
t
New or
Second Hand
Ifaw
ITew
Dew
Depth
300'
2400'
58001
indicated:
I Landed or 1
' Cemented '
; Cement
Gam ant ;
C eae n t ;
Sack]
Cement
150
700
150
If changes in the above plan become advisable we will notify you before cementing or landing casing. We estimate that
the first productive oil or gas sand should occur at a depth of about 0 JUU feet.
Additional information:
Approved
except as follows:
'-•--•: bo r-?27-_r.
cr.siii'? -.-oil.; i-
Title
-^.
Sincerely yours,
7_ Co
position ....... _ _21 .T Li s i on_5«i
Send communication regarding well to
Ho"b"D3. Men ::e^i3C
9 — ~ ---------
-------
« b, .ir.nt.th. OU
£& •;> «££ ^b^t
strv.ctkns in Rules and Regulation* of the Commission.
NE- MEXICO OIL CONSERVATION COJf " 1SIOX
Santa Fe, N«w Mexico
NOTICE OF INTENTION TO DRILL
a be'retumed following approval. Sea additio.
Place
Oil, CONSERVATION COMMISSION,
Sacta Fc-. New Mexico. .
G'n YoTare hereby notified that it is our intention to commence the drilling of a - all to be tadwn as
Dat<
0[ ;,
.re Oil and...E.efining.._C..Q.»
Company or Operator Lease
SO... T 1.9 _. R 2.7—, N. M. p. M^..._..llonum.en.t.
Well No 4 in._
Field,
of the -South lin« an
of the :jJss.t.Une of S«Oti-OB-50-19-37-
33Q...feet (N.)
The well is.
.(E.) I
(Give location from section or other legal subdivision lines. Cross out wrong direction
If state land the oil and gas lease Is No Assignment No _
If patented land the owner is .- '
Address
If government land the permittee is —
Address
The lessee is
AREA 6-10 ACRES
LOCATE WELL CORRECTLY
Address 3artl087illdj -Qfclahooa,
We propose to drill well with drilling equipment aa follows:.
-Tools
The status of a bond for this well in confonnance with Rule 39 of the General Rules and Regulations of the Commlii
as follows:
We propose to use the following strings of casing and to land or
Site of
Hoi*
Size of
Gating
12|-«
9 5/8"
7"
Weight Per Foot
50
40
24
New or
Second Hand
Hew
Sew
Hew
1 t
1
cement them as
1 Depth
300'
2400 f
5800'
indicated:
i Landed or Sacki
1 Cemented ! Ctmcnt
1 Cement
f Cement
: c ement
150
700
150
If changes in the above plan become advisable we will notify you before cementing or landing casing. We estimate
•the flrst productive oil or gas sand should occur at a depth of about 2.9.0.0JL—__feet.
Additional information:
Apnroved
except as follows:
J'JN
13..
r we].j.3 1*.
OIL CONSERVATION COMMISSION,
Ttle ......
Sincerely yours,
Satire Oi> and He fining
••" - """'"'
Position Us tric..t Qlarli....
Send communication regarding well to
Name D-...-...]},
-------
NEV , .iXICO OIL CONSERVATION COM*
Santa Fe, New Mexico
(Form C-lOU
(Revticd 7/1/12)
NOTICE.OF INTENTION TO DRILL
Notice m jjt be '-.'-vrSfi t? the District Office of the Oil Conservation Commission and approval .obtained sbefom drilling or rccomplction
fcriins. If charges in the 'propbs«l--plaiF*mie-»eon»id«red adwwable, a copy of this notice showing such changes'will be rfturnecl Jo the sender.
Subir.it this nonce in QUINTUPLICATE. One copy will be returned following approval. See additional instructions in Rules and Regula-
tions of the Commission.
Hobbs. Sew :iexLco
(Data)
(Plac«)
- IL CONSERVATION COMMISSION
S \NTA FE, NEW MEXICO
Gentlemen:
You are hereby notified that it it our intention to commence the (Drilling) (Recompletion) of a well to be known as
(Lean)
located _.13.Ci.t*r5 feet from the-
South
(Company or Operator)
^ Well No
in- £ _ The well is
(Unity
West
fi
_Jine and iP^O -feet from the
.-line of Section .20. , T. 12r§. , R Ji7rK , NMPM.
(GIVE LOCATION FROM SECTION LINE) ZtUKOrit „ Pool, Lea. _ County
If State Land the Oil and Gas Lease is No _
If patented land the owner it—
D
E
L
M
C
F
K
•
N
B
G
' J
O
A
H
I
P
We propose to drill well with drilling equipment as follows:...ROw.3Ty.
The status of plugging bond is..
Driliing Contractor.
Jiob.bs
We intend to complete this well in the .Q.U.6SO...
formation at an approximate depth of .355.5
CASING PROGRAM
We propose to use the following strings of Casing and to cement them as indicated:
..feet.
SU« of Hole
u lA
7 7/A
SIM of Culn*
8 5/3
5 V2
Wdcfat per Foot
24!
1Z,*
New or Second Hand
Nevr
few
Drptn
1250
3350
Smfkt Canrat
Circulate
LDQ
If changes in the above plans become advisable we will notify you immediately.
ADDITIONAL INFORMATION (If recompletion give full details of proposed plan of work.)
ation and non'-standard unit
Sincerely yours,
o^c any
-> N S /
OlL CONSERVATION COMMISSION
By.
Title
Send Communications n-izarding well 10
-------
C-760
-------
OKLAHOMA
C-761
-------
C-762
-------
Sampling Report
Investigation of Ward Petroleum Corporation's
Rowe Lease Well No. 1-20
Grady County, Oklahoma
June 26, 1986
SITE INFORMATION
Site Selection
This site was specifically selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). In the assignment of random sample
sites to various states, Oklahoma was not randomly picked for
sampling of drill wastes. Since Oklahoma drilling activity
equaled or exceeded the drilling activity of each of the other
sampling zones in 1984 (the most recent year drilling statistics
were available at the time of selection), it was considered
necessary to sample at least one Oklahoma drill site.
Sample site selection was negotiated with the Oklahoma Water
Resources Board, who in turn worked in cooperation with the
Oklahoma Corporation Commission. The objective was to sample a
relatively deep drill site in the Arcoma Basin which was at or
near completion. This site would be used to supplement data from
other states and basins in the onshore oil and gas sampling
program.
The site selected was the Ward Petroleum Corporation's Rowe Lease
Well No. 1-20, in Grady County, Oklahoma. No problems were
encountered in arranging sampling for June 26, 1986. No back-up
site was selected.
Site Location
The location of the Rowe Well No. 1-20 is approximately two miles
east of Alex, OK via highway 19 Grady County. Figure 1 is a map
indicating the drilling site. The full name and mailing address
for Ward Petroleum is:
Ward Petroleum Corporation
P.O. Box 3370
Enid, OK 73702
Main Office Contact: Claud Jackson, Vice President
Phone: 405-242-4444
Attendees
Sampling at the Rowe Lease site was performed by CENTEC
Corporation personnel on June 26, 1986. Following is a list of
people present at the time of sampling:
C-763
-------
Figure 1. Location of Ward Petroleum Corporation's Rowe
Lease Well #1-20, Grady County, Oklahoma
C-764
-------
CENTEC Corp. (Sample Team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
State Representatives: Fred Heitman, Head, Water
Quality Enforcement, Oklahoma
Water Resources Board
Richard Pierce, Field
Inspector, Oklahoma
Corporation Commission
Operator Representatives: Mark Rupert, Drilling and
Completion Manager
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Richard Pierce of the Oklahoma Corporation Commission briefly
visited the site as sampling was is progress. He did not speak
at length with the sampling team. Fred Heitman of the Oklahoma
Water Resources Board left the site with Mr. Pierce to have an
informal meeting regarding the sampling efforts. Mr. Heitman
returned to the site alone one hour later.
Site Description
The Rowe Lease site is located in rural flatland. The climate at
this site location is net evaporation. The soil is described as
a red clay bed three feet under loam. Attachment C contains a
soil report and analysis made available by Ward Petroleum. The
well was completed in the McLish formation of the Anadarko basin.
The well was to be tested in the McLish, Bromide, and Cunningham
formations. Figure 2 is a survey of the exact location of the
hole.
The depth to the groundwater in the area was estimated by the
drilling manager to be 5 feet. The nearest surface water is a
stream less than 1/2 mile west of the site. The nearest drinking
water well is 1,150 feet from the site.
At the time of sampling, the site consisted of one oil well and
one reserve pit. The drilling rig, Ward Drilling Company's Rig
No. 5, is shown in Photo 1. There were several trailers onsite
serving as offices and living quarters for the crew. These were
all situated on the edge of the pit. Figure 3 is an approximate
schematic diagram of the site, indicating the directions in which
photos were taken (Attachment A).
Attachment D contains copies of the drilling and completion
programs used by the drilling manager, made available by Ward
Petroleum Corporation.
C-765
-------
TOPOtt .IIC LAND SURVEYORS OF (IttA-—'. ..XPANY
r liw i»«*V MduW
.County. Oklanoma
.fU«9«_5a_I.M.
1506'FWl-IOOl'FH. Saeuon
ThfB location fwt tM l»9nf«t*d I
Figure 2. Survey of Well Location (size of copy has
been reduced)
C-766
-------
Figure 3. Schematic Diagram of Drilling Site
C-767
-------
This site was a developmental oil drilling site. The well was
completed at 14,900 feet, where the first test was performed.
Total depth had been reached at 15,000 feet. Drilling began on
February 19, 1986 and total depth was reached on June 25, 1986.
Completion of the well was expected to be final by July 20, 1986.
Drilling was accomplished with two fresh water base muds. These
are summarized in the table below:
Mud Type Depth Range (ft)
Spud Mud 0 - 7,000
Chrome-lignosulfonate 7,000 - 15,000
The spud mud contained a biocide product, "OK15" dithio
carbamate, that was used between 0 and 6,000 feet. From 6,000
feet to total depth, the biocide was no longer added to the mud.
One reserve pit was constructed onsite to provide temporary
storage of drill cuttings, residual drilling muds from the
circulation system, completion fluids, waste oil, and
miscellaneous trash. The pit contents were piped from the
drilling operation. The pit was in use as of February 19, 1986,
and was expected to be cleaned out and restored by September 1,
1986.
Figure 3 shows that the pit was constructed to conform to the
local geography, which is why the shape is asymmetrical. The
landowners to the east and west of the site would not allow the
pit to be extended into neighboring fields that were planted in
crops at the time of sampling.
To prevent groundwater contamination, the walls of the pit were
"rolled" to eliminate air holes, and the bottom was sealed with a
1/2- to 2-inch layer of bentonitic mud. The pit had nine
groundwater monitoring wells located along the east side of the
pit to prevent contamination of a drainage ditch running
north-south along the east side of the pit. The white pipes
visible in Photo 2 are three of the monitoring wells. The
monitoring wells consisted of gravel-packed slotted pipes placed
at depths of 15 and 28 feet. The monitoring wells and the
reserve pit were sampled once per week. Figure 4 is a copy of a
laboratory report on monitoring well and pit samples for the week
ending May 24, 1986.
The northern leg of the pit directly received drill cuttings from
the drilling rig. Photos 10 and 11 show the cuttings pile in
relation to the rig. Note that the cuttings had built up to a
volume that partitioned the liquid in the north leg from the
liquid in the triangular area of the pit. The pit was originally
constructed as one continuous volume.
C-768
-------
TfrfiN
(^tt
0
REPORT Chemical Laboratory Analysis
/-,:„„, Ward Petroleum
Water
CORPORATE OFFICE & CENTRAL LABORATORY
3400 N. Lincoln Okla. City. OK 73105 (405) 528-0541
Field Offices
902 Trails West Loop Enid. OK 73701 (405) 237-3130
900 S.E. 2nd Lawton. OK 73501 (405) 353-0872
208 Eastside Blvd. Muskogee. OK 74401 (918) E82-7B53
6WA60
Std.Mthd.,16th Ed
o-p^H ,« Don McCullough
Camp,flH from Rowe 11 Grady Co.. Ward R1g 15
fih,pp«,x/,. Don McCullough
hv rvHor of Don McCullough
hy
_ Received
client
5-23-86 ,
Date 5-22-86
Reported 6-19-86
Laboratory Number: 863711
Sample I.D.
Reserve Pit
II
13
15
Chloride
426mg/i
31.2mg/i
49.7*9/1
55.0mg/i
Sulfate
236ng/i
19.2mg/t
15.1mg/l
13.6mg/l
Chromium
1.76mg/l
0.04mg/i
0.03mg/l
0.04
-------
The depth of liquid in the pit varied from 1 to 4 feet, and the
depth of the sludge was approximately 1 foot.
Pit contents included approximately 25,000 barrels of cuttings,
drilling fluids, and wastewater generated from drilling
operations, waste engine oil, and approximately 125 barrels of
asphalt blend and Soltex used to protect the Springer shale
formation from excessive water loss during drilling. The
operator suggested that the asphalt blend and Soltex were
responsible for the visible sheen on the surface of the pit. In
addition, the water systems of the trailers along the sides of
the pit emptied directly into the pit. Thus, the pit contained
an unknown quantity of raw sewage.
A tank storing diesel onsite held roughly 9,500 gallons. Diesel
was being used at a rate of one tank-full every 5 to 6 days.
Twenty-five tanks had been used as of the time of sampling.
Disposal Practices
At the time of sampling, the drilling manager intended to apply
for a permit to reinject the reserve pit contents into an
acceptable formation at the drilling site. Approximately 4,000
barrels had already been removed from the pit and hauled by truck
to a centralized disposal well, owned by Road Runner Tank Trucks,
15 miles from the drilling site. If the application to reinject
the pit contents at the site was not accepted, the pit contents
would all go to the centralized disposal well. (The operator
later informed CENTEC that some of the liquid from the pit was
disposed of between the surface and production casing strings.
Any remaining liquids were to be trucked to a licensed disposal
pit.) The remaining solids were to be buried in the pit. The
pit would be backfilled and restored at the direction of the
landowner.
Permits
A copy of the drilling permit secured by Ward Petroleum Corp. for
the Rowe Lease Well No. 20-1 is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Rowe Lease site, the samples were defined as the
supernatant and solid contents of the waste material in the
reserve pit.
C-770
-------
Sample points were identified based on measurements of pit
dimensions. However, the asymmetry of the Rowe Lease pit did not
allow for placing sample points at the center of measured
quadrants, as is the practice for rectangular pits. Figure 3
indicates the location of the sample points.
Sampling Methods and Equipment
To collect samples from the reserve pit, measurements were made
to identify four points evenly spaced within the triangular area
and the northern leg of the pit. The measured points were marked
by placing stakes along the sides of the pit to facilitate
locating sample points.
The sample points were accessed by boat. The boat was rowed to
the measured sample points, and was stabilized at that point with
two anchors. Referring to the numbered sample points indicated
in Figure 3, the liquid samples were collected in the order 1, 2,
3, 4, and the sludge samples were collected in reverse order.
These numbers are only used to distinguish the four point
locations, and in no way refer to sample labels for tracking
purposes.
State representative, Fred Heitman, assisted in the boat for all
except the first liquid sample.
The first sample to be collected was the liquid composite.
Photo 16 shows samplers taking the first thief sample from the
boat. Care was taken not to allow oil floating on the surface of
the liquid to enter the thief. The liquid from each sample point
was composited in a 5-gallon carboy.
The reserve pit was then sampled for sludge. The coring device
was used at the two sample points in the northern leg of the pit,
yielding a combined volume of approximately 2 gallons. The
dredge was used to sample the triangular area of the pit because
the sludge was too liquid to be retained by the coring device.
Two full dredges were obtained at these points, yielding a total
volume of approximately 5 gallons. The solids were composited in
a steel bucket.
The pH of both the liquid and sludge samples was measured onsite
after sampling was completed. The pH for both samples was 8.
C-771
-------
C-772
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
'C-773
-------
o
Photo 2. Southwesterly view along side of
triangular area of pit
Photo 1. Drilling rig
-------
n
i
Photos 3,4,5. View of triangular area of pit from northeast corner
en
Photo 6. Close-up of liquid surface in pit
-------
o
I
Photo 7. Northern view along side of triangular area of pit
Photo 9. Northwestern view along
side of triangular area of pit
-------
Photo 10. Northern view of rectangular area of pit
Photo 11. Cuttings pile next to drilling rig
•>' "'*«. '"'•''-' I .
trjy •&.''•"' -
r^CL*^;-.;'<-'--'^ •- -
' "^ "i*tF^'il *~l&jl~' ''- ' - «•'
l^-i^ll«v4:a:''! -;.-..„
^^^^M^^^^A^^K
Photo 12. North end of rectangular area of pit
Photo 13. Cuttings line and pipe rack
-------
?,« ' '''is k-
Photo 14. Northwest corner of triangular area of pit
Photo 15. Northeast corner of triangular area of pit
-------
ATTACHMENT B: PERMITS
C-779
-------
C-780
-------
/;
OTC/OCC Operator Number.
"~ 2 ^7
** <--
Form No. 1000
(»ev. 1983)
2/1AFI number
I .* I ~? 94-
File Orlilnal Only
4. Nona or unornoH TO:
Drill ry1! Deepen t"~l Back | | Amended fX*1 Other
PLEASE TYPE OR PRINT IN BLAOC THK ONLT
INTENT TO DRILL APPLICATION
OKLAHOMA CORPORATION COMMISSION
Oil 4 Ga« Conaervatlon Division
Jim Thorpe Building
Oklahoma City. Oklahoma 73105-4993
(Bule 3-204)
O.C.C. Number
3. Locate Well and Outline
Lease or Spacing Unit
5. JfEU LOCATION: nr »u <•••»•
IT ami*. «M i
Section
ao
Township
srf
Bang*
County
Hell Location
Fact froa
tar S>etion4/
Ue.t
If unapacad - well will be.
6.
.fact lro» eb« aaaraat laaaa llna.
Wall **-&/- 3*
Phon« (AC/NuBbar)
Scat*
Zip
T3
2640
1980*
1320'
660'
2640'
1980'
1320'
660*
01
V*
LI
w
it
Dt
<> (t»«t) C«o»i«t (F««l
- //£>
±
2.2.00
£0
Al-fr
5 V4
1*100
1*7
At-
~e^'
I hereby certify that I am authorized to aubslt this application, which was prepared by me or under cy
supervision and direction. The facts and proposals made herein are true to the best of ay knowledge and
belief.
-------
C-782
-------
ATTACHMENT C: SOIL REPORT
C-783
-------
C-784
-------
REPORT
Billy B. Tucker, Ph.D.
Agronomist and Soil Scientist
I examined the proposed petroleum drilling site by Ward Petroleum Com-
pany in section 20, T 25N, R 5E on January 12, 1986. I examined two pro-
posed sites. One site was north of the highway and east of the waterway and
the other was on the south side of the highway and west of the waterway.
The soil on January 12, 1986 was probed to a depth of 4% feet. No
water table was encountered but a sand lens was found at about 40 inches
at the southern location. The sand lens was moist but no free water was
present. The Grady County Soil Survey showed the soil to be classified as
Yahola sand loam and Port loam. The survey reported no water table less
than six feet. Based on the inspection and soil survey a drilling pit with
a maximum depth of five feet was recommended. Also due to the slowly per-
meable permian red clay substrata it was felt that lining the pit would not
be necessary.
Upon excavation of the pit during location preparation, water seepage
was encountered at approximately three feet. I again examined the site on
January 31, 1986. Core borings in the pit revealed a water bearing sand lens
at approximately five feet below normal ground level.
The sand lens is approximatley 14 inches thick. The sand lens rests
upon red bed clay. Water in the bore holes rose to about the three foot level
indicating a slight hydrostatic pressure.
The yield of water from the sand lens would be small but probably con-
stant and likely would increase during probable spring rains before closure
of the pit. The water in the sand lens constitutes a perched water table.
C-785
-------
-2-
The shallowness of the perched water no doubt prevents it from being potable
for human consumption. In the waterway upstream from the location, on the
property line is a water hole and surface water frequently stands in the
waterway near the highway bridge.
Several alternatives to alleviate the water were explored. The water-
way adjacent to the location is about three feet deep which would not
drain off the water by gravity flow.
It was concluded that the only potential of ground water contamination
from an unlined pit would be the shallow perched water. However, due to
the possible movement of water down stream via the sand lens and the desire
of the land owner, lining of the pit is recommended. Pit materials will be
removed prior to closure.
Don Hale, Corporation Commission field representative at Duncan was
contacted and he concurred in the decision to line the pit.
Lining the pit and removing residual pit fluids and solids will vir-
tually eliminate the possibility of contamination of surface and ground
water and in addition will allow for satisfactory reclamation of the pit.
C-786
-------
ATTACHMENT D: DRILLING AND COMPLETION
PROGRAMS
C-787
-------
C-788
-------
DRILLING PROGRAM
Conductor Hole
Rig up rathole digger and drill 20" conductor hole to +/- 60'. Run
16" conductor casing and cement with regular grout.
Surface Hole
Drill out from conductor casing with 12 1/4" mill tooth bits.
Maintain mud weight as low as possible by frequent jetting of working
pits and running all solids control equipment. Utilize premix pit for
mixing gel-lime pills and recover as much of pills as possible by using
troughs .
Upon reaching +/- 2200 ', sweep hole with pill and make wiper trip
to surface prior to running casing. Lay down 8" drill collars prior to
running casing.
Rig up casing crew and run 9 5/8" casing as follows:
2200' 9 5/8" 36# K-55 ST&C
...using guide shoe and insert float valve. Use top and bottom plugs
and thread-loc guide shoe and collar that float valve is installed.
Tack weld first 5 connections and install centralizers on joints #1, 3
& 5.
Rig up cementing company and cement 9 5/8" casing using +/- 700 sx
"Lite" containing 2% CC and l/4#/sk celloflake and tail with 250 sx
Class "H" with 2% CC and l/4#/sk celloflake. Cement casing in full
tension and WOC a minimum of 4 hours before cutting off.
Production Hole
After cutting off, install 9 5/8" SOW x 10" - 5000 psi casinghead.
Pre-heat casing and head prior to welding casinghead and test weld to
1000 psi for 15 minutes. Nipple up 10" - 5000 psi BOP stack, mud
cross, and choke manifold, testing all equipment to rated pressure
except hydril and test it to 1500 psi. ('install mud gas separator and,
PVT^eguipment^ prior to drilling out.
Pick up 8 3/4" mill tooth bit and TIH to float collar. Pressure
test casing to 1000_psj.. Drill out using fresh water and continue using
l~geJ>lime pills for sweeps until +/- 7000'. Continue running solids
control equipment and jet working pits frequently to maintain low mud
weights. Depending on length of first mill tooth bit run, a "2" type
button bit may be run.
C-789
-------
At approximately +/-70001, begin mudding up the hole and
the following mud program to TD:
Depth
7000-8000
8000-9000
9000-10000
MW
8.8-9.0
9.0-9.4
9.4-9.5
10000-11000 9.5-10.3
Viscosity
/30-38
/ 38-40
I 40-42
42-50
WL
25-15
11000-12000
12000-13000
13000-14000
14000-14550
10.0-10.3^ / 50-65
10.0-10.3 / 60-70
10.0-10.3 / 70-80
10.0-10.3 ( 70-85
x_x
10L-3
3.0 or less
3.0 or less
3.0 or less
3.0 or less
3.0 or less
Remarks
WL must be
3.0 @ 10,000'
Start addim^
maintain @
Cut
As was seen on the Bradley Townsite well, it is imperative thai
the water loss be maintained as low as possible once we expose the
Springer scales to the drilling fluid. The addition of 2#/bbl Solti
should aid in stabilizing these water sensitive shales. Also, it K
be necessary to add oil or asphalt blend as a secondary control
mechanism.
As can be seen in the attached bit records, deviation problems
again become a problem from 9000' to TD. For that reason, coupled i
the slow penetration rates experienced running "slick" on the Bradli
Townsite, it is recommended that one or more of the following
assemblies be used to improve penetration rates while minimizing ho!
deviation:
1) Bit, 3 Pt-BH reamer, Rotating blade stab, 10' SDC, Rotating blai
stab, shock sub (if required), 1-30' DC, Rotating blade stab, 17-30
DC's, Drlg Jars, 3-30 ' DC's.
2) Bit, 3 Pt-BH reamer, 2-Rotating blade stab, 10' SDC, Rotating b!
stab, Shock sub (if required), 1-30' DC, Rotating blade stab, 17-30
DC's, Drlg Jars, 3-30' DC's.
3) Bit, 2-30' DC's, 1 or 2-Rotating blade stab, 10' SDC, Rotating
blade stab, Shock sub (if required), 1-30' DC, Rotating blade stab,
17-30' DC's, Drlg Jars, 3-30' DC's.
should be noted that a 6 Pt-BH reamer should be employed whils
the__ Simpson sands to mainfaTn mavJTmiTn aoiT Prior to
- __
committing any of these or other assemblies in the hole, discussion
should be held with drilling company and operating personnel
Bit selection should be as follows:
a) Type 2 and Type 3
b) Type 5 and Type 7
c) Type 9
d) Type 5 and Type 7
3500' to 13000'
13000' to 13600'
13600' to 14000'
14000' to 14550'
C-790
-------
Bit selection should be coordinated with the mudlogger and/or
geologist to aid in maximum effectiveness.
After reaching logging point of +/- 14,450', circulate bottoms up
and make 20 stand short trip prior to POOH to log. Run logs as
directed by geologic staff. After logging, TIH w/bit to condition hole
and WOO as to running 5 1/2" casing or plug and abandon.
If logs indicate production, run casing as dictated in the
Completion Section.
If logs indicate the well is dry, plug and abandon the well as
directed by the Oklahoma Corporation Commission.
C-791
-------
GENERAL COMPLETION PROGRAM
Rowe #1-20
Production Hole
After conditioning hole to run casing, POOH and lay down 6 3/4'
drill collars and 4 1/2" drill pipe. Rig up casing crew and run cai
(bottom to top) as follows:
1000' 5 1/2" 20# S-95 LT&C
5300' 5 1/2" 20# N-80 LT&C
3900' 5 1/2" 171 N-80 LT&C
2200' 5 1/2" 20# N-80 LT&C
2600' 5 1/2" 20# P-110 LT&C
using standard float shoe and float collar, with float collar t
be run two joints above shoe. Thread-loc float shoe, float collar,
in between collar. Install centralizers as directed.
After reaching bottom with casing, circulate bottoms up and lei
mud weight out. Work pipe every 15 minutes while circulating and se
casing one foot off bottom prior to cementing.
Rig up cementing company and cement based on caliper volumes an
cement requirements. Use top and bottom plugs and displace hole wit
6% KCL water. Bump plug with +/- 1000 psi over displacement pressur
and bleed off pressure to check floats.
Assuming floats hold, WOC a minimum of 8 hours prior to setting
slips. Set slips as directed by Engineering staff. Install 10" -5
psi x 7 1/16" - 5000 psi tubinghead and 1-2 9/16" - 5000 psi master
valve.
Release rig and move off rotary tools.
C-792
-------
Sampling Report
Investigation of George Kahn Operating Company's
Mary Allen Tank Battery
Oil Center/ Oklahoma
June 27, 1986
SITE INFORMATION
Site Selection
This site was specifically selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). In the assignment of random sample
sites to various states, Oklahoma was not randomly picked for
sampling of produced fluids. Since Oklahoma production exceeded
the production of five other sampling zones in 1984 (the most
recent year statistics were available at the time of selection),
it was considered necessary to sample at least one Oklahoma
production site.
Sample site selection was negotiated with the Oklahoma Water
Resources Board, who in turn worked in cooperation with the
Oklahoma Corporation Commission. The objective was to sample an
active production site in the Arcoma Basin. This site would be
used to supplement data from other states and basins in the
onshore oil and gas sampling program.
The production site selected was the George Kahn Operating
Company's Mary Allen Tank Battery near Oil Center, Oklahoma. No
problems were encountered in arranging sampling. No back-up site
was required.
Site Location
The George Kahn production facility is located approximately 45
miles southeast of Oklahoma City, OK via Highways 35, 39, and 3W
in Pontotoc County. Figure 1 is a map indicating the production
facility site. The full name and mailing address for Chevron USA
is:
George Kahn Operating Company
P.O. Box 1287
Seminole, OK 74868
Main Office Ph.: 405-382-1566
Main Office Contact: Mike Kahn or
Richard Parrish, Attorney
Attendees
Sampling at the George Kahn production site was performed by
CENTEC Corporation personnel on June 27, 1986. Following is a
list of people present at the time of sampling:
C-793
-------
4 7'30" ,'02
a 11) \' 29 •*
i -f II I *3 I •r
-
SITE LOCATION
I / .)""".! J.rfl" I"I 'V-Jav// '«/
--. '/_,-' .r-'f-/; •rMfJ/V;\/
^aiM^ilKf^a^'i
^VTM"^, trfnWoM^
r^>w i?i
\:-^r/^:-Vfi fj A
, r-^- ^ h - r'-••'•. . / vx.Utv
\y \v fif^
-.1 \SFt r---*
Figure 1. Location of George Kahn Operating Company's Mary
Allen Tank Battery, Oil Center, Oklahoma
C-794
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CENTEC Corp. (Sample Team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
State Representatives: Doyle Harrell, Field Inspector,
Oil and Gas Division,
Oklahoma Corporation
Commission
Karen Dihrberg, Geologist,
Oklahoma Water Resources
Board
Operator Representatives: None Present
American Petroleum Institute
Representative: George Holliday, Contracted
Observer
Information about the site was provided by Mr. Harrell, based on
his experience with the operator and local production facilities.
Site Description
The George Kahn production facility is located in a rural,
piedmont area. The climate at this site location is net
precipitation. The soil is described as loam over clay. The
wells serviced by this facility are completed primarily in the
Viola Simpson formation, but also in the Hunton, Calvin, and
Wewoka formations.
The depth to the groundwater in the area is approximately 250
feet. The nearest surface water is a farm pond located 1/4-mile
from the site. There are one or two drinking water wells within
a 1/2-mile radius of the site.
The area around the site was being used as grazing land for cows
at the time of sampling. There were no fences or cattle guards
to block access to the site.
The site consists of one gun barrel, one heater treater, two
separation tanks, four stock tanks, and two produced water tanks.
Figure 2 is an approximate schematic diagram of the facility,
indicating the directions in which photos were taken (Attachment
A) . The Oklahoma Corporation Commission does not require
cleaning of tanks, so it is assumed that the tanks on this site
are never cleaned. The produced water tanks are open to the
atmosphere at the top (Photo 11), and are made of fiberglass.
At the time of sampling, there were 21 oil wells associated with
this tank battery, but the number of producing wells was unknown.
The facility received daily quantities of approximately 3 barrels
of oil per producing well. The volumetric ratio of oil to water
from this formation was estimated to be one to fifty, indicating
C-795
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Figure 2. Schematic Diagram of Production Facility
C-796
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a daily rate of 75 barrels of produced water per well. Depths of
wells on this lease vary from 2,500 to 2,600 feet.
Disposal Practices
The produced water was discharged to the surface via pipe from
the produced water tanks. The relationship of the discharge
point to the tank battery is shown in Photo 4. Photos 6, 7,
and 8 show the path of the discharge stream down the hill away
from the tank battery. A closeup of the discharge point, Photo
5, indicates a buildup of what might be sulfur along the path of
the discharge. The assumption that the substance is sulfur was
based on its yellowish appearance and a definite sulfur smell
throughout the area.
Permits
State representative Doyle Harrell informed the sample team that
direct discharges such as the one at this site are permitted by a
special Corporation Commission order, established in 1973.
Permission to discharge water directly is based on chlorides
content. No operating permits were made available to the sample
team at the time of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the George Kahn site, the sample was defined as the fluid in
the produced water tanks that discharge the water directly. One
of the produced water tanks was sampled instead of the discharge
pipe shown in Photo 4 because a sample bottle could not be placed
under the flow from the pipe without fouling the sample.
Figure 2 indicates the sample point from which the fluid sample
was composited.
Sampling Methods and Equipment
As shown in Photo 11, the fluid sample was obtained from the open
top of the southern produced water tank. The depth of the water
in the tank was measured as 6 feet. Thief volumes were taken at
depths of 1-1/2, 3, 4-1/2, and 6 feet below the surface, and
composited in a 5-gallon glass carboy. Photo 12 is a closeup of
the composited sample in the carboy, and the sampling thief.
There was a 1- to 2-inch layer of oil on the surface of the water
in the tank. Care was taken not to allow the oil to enter the
thief as the sample was collected, but there was difficulty
keeping the outside of the equipment clean.
C-797
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The pH of the produced fluid sample was measured onsite after
sampling was completed. The pH was in the range between 8 and 9
C-798
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ATTACHMENT A: PHOTO DOCUMENTATION OP
SAMPLING ACTIVITIES
C-799
-------
C-800
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Photo 1. Production tankage
n
I
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o
Photo 2. Production tankage
Photo 3. Production tankage
-------
00
o
10
Photo 4. Produced fluid tanks and
the I r d I scharge
Photo 5. Discharge from produced fluid tanks
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«%/&•!'*-~^~H8
|P||gPj
Photo 7. Discharge from produced fluid
tanks flowing down hill
Photo 8. Discharge from produced fluid
tanks flowing down hill
Photo 9. Produced fluid tanks (right) and production
tankage (background)
C-803
-------
o
I
00
o
Photo 10. Produced fluid tanks
Photo 12. Liquid composite and thief
after samp I i ng
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ATTACHMENT B: PERMITS
C-805
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C-806
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No permit specific to the operation
of this site is available.
C-807
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C-808
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Sampling Report
Investigation of Royce Kelly's
Centralized Disposal Pit
McClain County/ Oklahoma
June 29, 1986
SITE INFORMATION
Site Selection
This site was specifically selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). An offsite pit was selected for
sampling in Oklahoma for two reasons. First, the limited
sampling of drill sites in Oklahoma was disproportionate to its
drilling activity. (See Appendix B of the EPA Technical Report
(EPA 530-SW-87-005).) Second, the Oklahoma Corporation
Commission's permitting of offsite pits for disposal of drilling
wastes made it desireable to sample these commingled wastes.
Sample site selection was negotiated with the Oklahoma Water
Resources Board, who in turn worked in cooperation with the
Oklahoma Corporation Commission. The objective was to sample an
active offsite drilling waste disposal pit. This site would be
used to supplement data from other areas of the U.S. in the
onshore oil and gas sampling program.
The Royce Kelly Centralized Disposal Pit in McClain County,
Oklahoma, was selected for sampling. No problems were
encountered arranging for samples to be taken June 29, 1986. No
back-up site was required.
Site Location
The Royce Kelly Centralized Disposal Pit is located approximately
6 miles northwest of Purcell, OK via Highway 74 in McClain
County. Figure 1 is a map indicating the disposal pit site. The
full name and mailing address for Royce Kelly is:
Royce Kelly Disposal
P.O. Box 98
Maysville, OK 73057
Main Office Ph.: 405-867-5606
Contact (Consulting Engineer): Mr. Royce Kelly, Land
Owner and Operator
Attendees
Sampling at the Royce Kelly site was performed by CENTEC
Corporation personnel on June 29, 1986. Following is a list of
people present at the time of sampling:
C-809
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Figure 1. Location of Royce Kelly's Centralized Disposal
Pit, McClain County, Oklahoma
C-810
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CENTEC Corp. (Sample Team):
State Representative:
Operator Representative:
American Petroleum Institute
Representatives:
Bill Lane, Technician
Jamie Mclntyre, Team Leader
Fred Heitman, Head, Water
Quality Enforcement, Oklahoma
Water Resources Board
Royce Kelly, Land Owner and
Operator
George Holliday, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
Earl Kinsley, Contracted Sample
Team Member
Site Description
The Royce Kelly site is located in a rural, prairie land area.
The climate at this site location is net evaporation. The soil
is described as clay.
The depth to the groundwater in the area was estimated to be
between 26 and 50 feet, based on the depths of water wells in the
area. The nearest surface water is a stream located less than
1/2 mile from the site. There is one drinking water well located
less than 1/4 mile from the site, and one well between 1/4 and
1/2 mile from the site.
At the time of sampling, the site consisted of two disposal pits.
Figure 2 is an approximate schematic diagram of the site, indi-
cating the directions in which photos were taken (Attachment A).
The southern pit is designated as Pit #2, and the northern pit is
Pit #3. Both pits are used for disposal of oil well drilling
wastes brought to the facility by truck from surrounding
counties, including McClain, Oklahoma, Cleveland, Garvin, and
Grady. Photo 12 shows a truck unloading sludge into Pit 12. The
current charge for disposing into the pit at the time of sampling
was $0.25 per barrel.
Pit #2 was first used for disposal of drilling wastes in 1984,
and Pit #3 was first used in 1985. Both pits will continue to be
used for this purpose for the next 7 to 8 years, depending on the
status of the oil industry.
The wastes brought to the site generally consist of drilling
muds, drill cuttings, and fresh water. The operator tests every
load that comes to the site for chlorides content. The site will
not accept any waste that has greater than 1,500 parts per
million chlorides. The Oklahoma Corporation Commission (OCC)
also tests the pit, once per month. The OCC tests for chlorides,
chromium, arsenic, and other compounds.
C-811
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4,
Figure 2. Schematic Diagram of Centralized Disoosal Pits
C-812
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Both pits at the site are lined with one foot of bentonite clay.
The sides of the pits have a 4:1 slope. Compaction of the soil
within the pit must be 104-112 percent, and this is tested
frequently. Both pits were designed to be 40 feet deep.
Pit #2 was nearly full at the time of sampling, and contained
sludge with a negligible layer of liquid on top. Pit #3
contained water with an average depth of 24 feet, and sludge an
estimated 20 feet deep.
Leak detection monitoring is accomplished by a 25-foot deep
monitoring well located 1/4 mile south of the pit site. The well
is positioned downstream from the disposal pits in regard to
groundwater flow. The well is cemented between 12 and 14 feet
and is perforated and gravel-packed.
Permits
No operating permits were made available to the sample team at
the time of sampling. However, the sign in Photo 1 shows an
Order No. 218841 which was issued to the site by the OCC.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005) .
Sample Point Locations
At the Royce Kelly site, the samples were defined as the
supernatant and solid contents of the waste material in Pit #3.
Pit #2 was not considered for sampling because it had no liquid
layer over the sludge.
Sample points were accessed by boat. Figure 2 indicates the
measured sample points as well as the actual sample points from
which the pit samples were composited.
Sampling Methods and Equipment
To collect samples from Pit #3, the pit was measured to identify
the four quadrants shown in Figure 2, and to locate the center of
each quadrant. The measured points were marked by placing stakes
along the sides of the pit to facilitate locating sample points.
Photo 6 shows samplers measuring the levy between Pits 12 and #3.
Sampling was performed by state representative Fred Heitman and
CENTEC technician Bill Lane. The boat was rowed to the marked
sample points and held in place with two anchors. Photo 16 shows
samplers in the boat aligned with a stake on the side of the pit.
C-813
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The first sample to be collected was the liquid composite. The
thief was used to obtain this sample.
The pit was then sampled for sludge. The coring device was not
used because the depth of the liquid in the pit was between 21
and 27 feet, and the equipment would have been dangerous to
handle under these conditions. Two dredge-fulls were obtained at
each quadrant, yielding a total volume of approximately 5
gallons. The solids were composited in a steel bucket.
The samples were tested onsite for pH after sampling was
completed. The pH was 8 for both the liquid and sludge samples.
The samples were preserved with ice and held overnight prior to
the day of shipment. This was necessary because of time
constraints encountered on the day of sampling.
C-814
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ATTACHMENT At PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-815
-------
C-816
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Photo 1. Shed next to pits
Photo 2. Northerly view of pit 12
from southwest corner
Photo 3. Westerly view of dike between pits
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f'** '•*' * ••
-••^T^-^t^*-^V-^^-^-3*- •^^~^lz- -—: '-^ •~~" ' ~~ -^"*-^
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Photos 4,5. Southerly view of pit §2, dike, and pit #3
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Photo 7. Southerly view of pit t2
Photo 8. Outside west wall of pit 12
o
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vo
Photos 9,10. Southerly view of trailer at north end of pit #2
-------
Photo 11. Northerly view of trailer at north end
of pit »2
Photo 12. Truck unloading Into plt#3
-------
o
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CD
Photo 15. Road leading to site
Photo 16. Samplers In pit #2
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C-822
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ATTACHMENT B: PERMITS
C-823
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C-824
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No permit specific to the operation
of this site is available.
C-825
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C-826
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PENNSYLVANIA
C-827
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C-828
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Sampling Report
Investigation of Franklin Brine Treatment Corporation
Franklin, Pennsylvania
September 3, 1986
SITE INFORMATION
Site Selection
This site was specifically selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). The selection was based on personal
communication with the Pennsylvania Department of Natural
Resources, Bureau of Oil and Gas Management. At the request of
EPA, the Department of Natural Resources identified three
facilities treating oil and gas wastes in Pennsylvania. Of the
three sites, the Franklin Brine Treatment Corporation was
actively receiving and commingling drill wastes, fracturing
fluids, and produced water prior to treatment. Their treatment
consisted of aeration, skimming, neutralization, flocculation,
decantation, and disposal of liquid and solids.
EPA specifically selected the Franklin Brine Treatment
Corporation facility to obtain technical information and
analytical data regarding the practice of using centralized
facilities to treat and dispose of wastes from multiple oil and
gas sources in Pennsylvania. The Agency is interested in the
developing information about the constituents of the wastes, and
about the effectiveness of the treatment processes. A more
detailed discussion of the rationale for selection of centralized
treatment facilities is contained in Appendix B.
No problems were encountered arranging for sampling to be
conducted on September 3, 1986.
Site Location
Franklin Brine Treatment Corporation is located 2 miles east of
Franklin, PA on Route 322. Figure 1 is a map indicating the
treatment site.
The site is operated by Franklin Brine Treatment Corporation,
whose mailing address and telephone number are:
PO Box 728
Franklin, PA 16323
814-437-3593
The facility is owned by Cabot Corporation, Boston, MA.
C-829
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COMMONWEALTH OF PENNSYLVANIA
DEPARTMENT OF ENVIRONMENTAL RESOURCES
TOPOGRAPHIC AND OEOLGIC SURVEY
47'30"
Figure 1. Location of Franklin Brine Treatment Corporation,
Franklin, Pennsylvania
C-830
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Attendees
Sampling of Franklin Brine Treatment Corp. was performed by
CENTEC Corporation personnel on September 3, 1986. The following
is a list of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representative:
Operator Representatives:
American Petroleum Institute
Representatives:
Other Observers:
Site Description
Bruce Hoskins, Team Leader
Jim Kourmadas, Technician
Jim Erb, Bureau Chief, Oil and
Gas Management, PA Department
of Environmental Resources
Rudy Adamiak, Manager, Franklin
Brine Treatment Corporation
Jim Trimble, Regional Manager,
Cabot Oil and Gas Corporation
Fred Shelton, Safety Super-
visor, Cabot Oil and Gas
Corporation
Dave Ballard, Environmental
Supervisor, Cabot Oil and Gas
Corporation
George Holliday, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
Cliff Griffith, PA Natural Gas
Association, Environmental
Committee
Franklin Brine Treatment Corporation is located in the
Appalachian Basin in an area characterized as suburban and
mountainous. The depth to groundwater is 62 feet, and the
nearest surface water (the Allegheny River) is 250 feet away.
There are three drinking water wells within a 1-mile radius from
the site; the closest well is within a 1/4-mile radius from the
site. The soil in this area is clay. The climate at this site
is net precipitation.
This site is a central treatment facility for oil and gas
produced brines. The facility became operational in May 1985 and
began commercial operations in July 1985. Monthly operation
hours are 400; annual operation hours are 4,760. Clients are
within a 0- to 240-mile radius of the facility- The facility
charges between $0.02 and $0.11 per gallon for processing. Price
incentives are given for larger volumes.
C-831
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Figure 2 is a schematic diagram of the treatment facility. The
operation is a batch process with a daily permitted capacity of
205,000 gallons. The operation constitutes final treatment prior
to discharge to the Allegheny River.
Photo 1 (Attachment A) shows the truck unloading area. The brine
proceeds to one of two storage tanks, shown in Photo 2. The
facility consists of a treatment sequence of oil skimming,
aeration, pH adjustment by lime addition followed by polymer
addition, flocculation, and settling. From the settler, the
treated water flows into a sample monitoring tank before flowing
into a series of manholes where it is finally discharged. The
solids flow into a sludge decant tank and then into a manually
operated plate and frame filter press shown in Photo 3. All
recovered water from the filter press is recycled into the
neutralization tank. The sludge is sent to a landfill. Wash
water is recycled into the neutralization tank. Daily volume of
the operation is variable; a gallon of influent brine produces an
average of 0.8 pounds of sludge.
The chemicals used in the process are bulk hydrated lime, Nalco
7182 anionic flocculant, Nalco 71-D5 antifoamant, and Chemex 750
surfactant. Chemex 750 surfactant is used for equipment washing.
The facility uses a manifest system to- account for all influent.
A copy of the manifest is shown in Attachment C.
Permits
This facility operates under PA NPDES Permit No. 0101508, as
shown in Attachment B. This permit requires the monitoring of
the following discharge parameters: total suspended solids, oil
and grease, aluminum, dissolved iron, osmolality, total dissolved
solids, chlorides, and pH. The required frequency for monitoring
these parameters is once per week, except for pH which must be
measured daily and osmolality which must be measured once every 6
months (see permit for required discharge limitations).
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Franklin Brine Treatment Corp. consisted
of two liquid samples (influent and effluent) and one sludge
sample. The influent sample was collected at one of the brine
feed pumps at the base of the brine tanks. The sample location
C-832
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"JHOff L*7—'
TRUCK UNLOADING
o
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oo
w
oo
LIME FEED
SYSTEM
BRINE STORAGE TANKS
TO
••ALLEGHENY
RIVER
NEUTRALIZATION
TANK
SETTLER
SLUDGE
DECANT
TANK
MONITOR/ METERING
SAMPLE MANHOLE
TANK
PLATE a FRAME
FILTER PRESS
SUMP
SOLIDS TO
DISPOSAL
Franklin Brine Treatment Corporation
Figure 2. Flow Diagram-
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is shown in Photo 4. The effluent sample was collected from the
final metering manhole before discharge to the Allegheny River.
The location is shown in Photo 5. The sludge sample was taken
from the plate frame and filter press. The sludge collected
represented the solid waste from the facility's most recent batch
operation.
Sampling Methods and Equipment
The influent sample was collected with a 5-gallon glass carboy
from a pump valve at the brine feed pump in Photo 4. The
effluent sample was taken with a stainless steel bucket which was
lowered into the manhole with a rope. The sludge sample was
collected by removing the sludge from the plate frame and filter
press and placing it in a stainless steel bucket.
Tests for the pH and free chlorine content of the liquid influent
and effluent samples were conducted onsite after sampling was
completed. The liquid influent pH was measured at 6; the
effluent pH was measured at 10. The free chlorine content of
both liquid streams was measured at less than 0.2 ppm (i.e., none
detected).
C-834
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-835
-------
C-836
-------
Photo 1. Truck unloading area
O
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CD
U)
Photo 2. Brine storage tanks
Photo 3. Sludge filter press
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Photo 4. Influent sample collection point
Photo 5. Effluent sample collection point
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ATTACHMENT B: PERMITS
C-839
-------
C-840
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.ER-BWQ-15.1 9/78 (Rev. 5/81)
COMMONWEALTH OF PENNSYLVANIA
DEPARTMENT OF ENVIRONMENTAL RESOURCES
BUREAU OF WATER QUALITY MANAGEMENT
AUTHORIZATION TO DISCHARGE UNDER THE
NATIONAL POLLUTANT DISCHARGE ELIMINATION SYSTEM
INDUSTRIAL PERMIT NO. PA 0101508 Amendment No. 2
In compliance with the provisions of the Clean Water Act, 33 U.5.C. Section 1251 et
seq. (the "Act") and Pennsylvania's Clean Streams Law, as amended, 35 P.S. Section 691.1
et seq.,
Franklin Brine Treatment Corporation
is authorized to discharge from a facility located at "
Cranberry Township, Venango County
to receiving waters named
Allegheny River
in accordance with effluent limitations, monitoring requirements and other conditions set
forth in Parts A, B, and C hereof.
This permit and the authorization to discharge shall expire at midnight,
Nnvfimbpr 23,
The authority granted by this permit is subject to the following further qualifications:
1. If there is a conflict between the application, its supporting documents and/or
amendments and the terms and conditions of this permit, the terms and conditions
shall apply.
2. Failure to comply with the terms or conditions of this permit is grounds for
enforcement action; for permit termination, revocation and reissuance, or
modification; or for denial of a permit renewal application.
3. Application for renewal of this permit, or notification oi intent to cease discharging
by the expiration date, must be submitted to the Department at least 180 days prior
to the above expiration date (unless permission has been granted by the Department
for submission at a later date), using the appropriate NPDES permit application
form. In the event that a timely and complete application for renewal has been
submitted and the Department is unable, through no fault of the permittee, to
reissue the permit before the above expiration date, the terms and conditions of this
permit will be automatically continued and will remain fully effective and
enforceable pending the grant or denial of the application for permit renewal.
4. This NPDES permit does not constitute authorization to construct or make
modifications to wastewater treatment facilities necessary to meet the terms and
conditions of this permit.
PERMIT ISSUED
This permit supercedes Permit
#0101508 issued 11-24-82.
DATE . _ _^____
1T1985
BY
Peter A. Yeager, P.E.
Regional Water Quality Manager
TITLEMeadvillo Regional Offirp
C-841
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COMMONWEALTH OF PENNSYLVANIA
DEPARTMENT OF ENVIRONMENTAL RESOURCES
STANDARD CONDITIONS RELATING TO INDUSTRIAL WASTES
For Use In Water Quality Management Permits
1971
General
1. The plans for which this permit is issued are approved subject to the condition that the waste treatment plant
constructed under said plans will produce an effluent satisfactory to the Department. By this approval, neither the
Department nor the Commonwealth of Pennsylvania assumes any responsibility for the feasibility of the plans or
the operation of the plant to be constructed thereunder.
2. All relevant and non-superseded conditions of any prior water quality management permits, decrees, or orders
issued to the herein permittee or his predecessor shall be continued in full force and effect and together with the
provisions of this permit shall apply to his successors, lessees, heirs and assigns.
^ 3. The responsibility for the carrying out of the conditions of this permit shall rest upon the owner, lessee, assignee,
N or other party in responsible managerial charge of the operation producing the wastewaters and of the waste
treatment works herein approved, such responsibility passing with each succession in said control. Approval of a
discharge or facilities under a permit shall not be effective as to a new owner until a transfer has been executed
and filed on forms provided by the Department and the transfer is approved by the Department.
^. The permittee shall secure any necessary permission from the proper federal authority for any outfall or industrial
waste treatment structure which discharges into or enters navigable waters and shall obtain approval of any stream
crossing, encroachment or change of natural stream conditions coming within the jurisdiction of the Department.
5. In order to avoid obsolescence of the plans of waste treatment works, the approval of the plans herein granted, and
the authority granted in the permit, if not specifically extended, shall cease and be null and void two years from
the date of this permit unless the works covered by said plans shall have been completed and placed in operation on
or before that date.
6. Approval of plans refers to functional design and not structural stability, which is assumed to be sound and in
accordance with good structural design. Failure of the works herein approved because of faulty structural design or
poor construction will render the permit void.
\ 7. The Department may at a subsequent time modify, suspend or revoke this permit whenever the waters affected by
the presently authorized waste discharge have become so improved in character through natural or artificial
processes of conservation or reclamation as to render inimical or harmful the effluent from the works herein
approved, or whenever the Department increases treatment requirements for wastes generally.
Therefore, the permittee is hereby notified that when the Department shall have determined that the public
interest requires the further treatment of such of the permittee's industrial wastes as are discharged to the waters
of the Commonwealth, then upon notice by the Department and within the time specified, the permittee shall
submit to the Department for its approval, plans and a report providing for the required degree of treatment, and
after approval thereof, shall construct such works in accordance with the requirements of the Department.
\ 8. If at any time the industrial waste treatment works of the permittee, or any part thereof, or the discharge of the
effluent therefrom, shall have created a public nuisance, or such discharge is causing or contributing to pollution of
the waters of the Commonwealth, the permittee shall forthwith adopt such remedial measures as are acceptable to
the Department.
9. Nothing herein contained shall be construed to be an intent on the part of the Department to approve any act made
or to be made by the permittee inconsistent with the permittee's lawful powers or with existing laws of the
Commonwealth regulating industrial wastes and the practice of professional engineering, nor shall this permit be
construed to sanction any act otherwise forbidden by any of the laws of the Commonwealth of Pennsylvania or oi
the United States.
Construction
10.
11.
The works shall be constructed under expert engineering supervision and competent inspection, and in accordance
wnn plans, designs, and other data as herein approved or amended, and with the conditions of this permit.
shall be made in the works herein approved without approval of the Department. Revisions
H!<:rhara» m=; V3Se rate of flow or change the quality of the effluent, the treatment processes or the point ot
approved by rpermitPPr°Ve ^ Regional Sanitary Engineer upon submission of plans. Other revisions must be
C-842
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12. The outfall sewer or drain shall be extended to low water mark of the receiving body of water in such a manner as
to insure the satisfactory dispersion of its effluent thereinto; insofar as practicable it shall have its outlet
submerged; and shall be constructed of cast iron, concrete, or other material approved by the Department; and
shall be so protected against the effects of flood water, ice, or other hazards as to reasonably insure its structural
stability and freedom from stoppage.
13' ^!?:*lllt hurfn aPProved industrial waste treatment works is completed and before it is placed in operation, the
"m'""~ sna11 notify the Department so that an inspection of the works may be made by a representative of the
Operation and Maintenance
1«. No matter how well designed and carefully constructed a waste treatment works may be, full effectiveness cannot
V oe developed unless it is efficiently operated. In order to secure such efficiency, protect the waters of the
\ v-ommonwealtn, and insure the most effective and economical dosage when chemicals are used, the permittee is
required Jo place the works under the regular charge of a responsible plant official, and its operation under the
control 01 the designer of the works or other qualified person approved by the Department, for at least one year
aiier completion. Moreover, upon written notice from the Department, the permittee shall maintain one or more
skilled operators regularly on duty for such daily periods as the Department may direct.
\ 15. The right to discharge the effluent from the herein approved industrial waste treatment works into the waters of
oua|-t°mmt°nfWe 'S Contin6ent uP°n such operation of these works as will at all times produce an effluent of a
quality satisfactory to the Department. If, in the opinion of the Department, these works are not so operated or if
oy reason of change in the character of wastes or increased load upon the works, or changed use or conditon of the
receiving body of water, or otherwise, the said effluent ceases to be satisfactory for such discharge, then upon
notice by the Department the right herein granted to discharge such effluent shall cease and become null and void
umess within the time specified by the Department, the permittee shall adopt such remedial measures as will
produce an effluent which, in the opinion of the Department, will be satisfactory for discharge into the said
receiving body of water.
16. No untreated or ineffectively treated wastewaters shall at any time be discharged into the waters of the
Commonwealth, and especial care shall be used to prevent accidental "spills" or similar unusual discharges of all
raw, finished and waste materials.
7. No storm water, sewage or other industrial wastes not specifically approved herein, shall be admitted to the works
lor wmch this permit is issued, unless with the approval of the Department.
The various structures and apparatus of the industrial waste treatment works herein approved shall be maintained
in proper condition so that they will individually and collectively perform the functions for which they were
esigned. In order to insure the efficacy and proper maintenance of the treatment works, the permittee shall make
periodic inspections at sufficiently frequent intervals to detect any impairment of the structural stability, adequate
capacity, or other requisites of the herein approved works which might impair their effectiveness, and shall take
immediate steps to correct any such impairment found to exist.
Any screenings, and any settled or floated solids, shall at no time be permitted to accumulate in sedimentation
oasins to a depth sufficient to interfere with the settling efficiency thereof. Any such material removed shall be
handled and disposed of so that a nuisance is not created and so that every reasonable and practical precaution is
taKen to prevent the said material from reaching the waters of the Commonwealth.
The permittee shall keep records of operation and efficiency of the waste treatment works and shall submit to the
Department, promptly at the end of each month, such report thereon as may be required by the Department.
t t discnarSe of untreated or improperly treated industrial wastes to the waters of the Commonwealth is contrary
to the requirements of the Department. If, because of accidental breakdown of the treatment works or plant
equipment or for other reason, any such discharge should occur, then the operation of the mill or process producing
ucn discharge shall be discontinued until repairs to the treatment works or other satisfactory measures to prevent
water pollution shall have been completed.
C-843
-------
DEPARTMENT OF ENVIRONMENTAL RESOURCES
STANDARD CONDITIONS RELATING TO EROSION CONTROL 1985
For Use in Water Quality Management Permits
1. By approval of the plans for which this permit is issued, neither the Department nor the Commonwealth of
Pennsylvania assumes any responsibility for the feasibility of the plans or the operation of the measures and
facilities to be constructed thereunder.
2. If at any time the erosion and sedimentation activities undertaken pursuant to this permit or the discharge of
the effluent therefrom is causing or contributing to pollution of the waters of the Commonwealth, the
permittee shall forthwith adopt such remedial measures as are acceptable to the Department.
3. This permit does not authorize any earth disturbance controlled by an ordinance enacted by a local
municipality. Additional permits must be secured from local municipalities where earthmoving activities are
covered by local ordinances.
4. At least seven days before earthmoving will begin, the permittee, by telephone or certified mail, shall notify
the Department or its designee of the date for beginning of construction and invite the County Conservation
District Representative to attend a pre-construction conference with the contractor.
5. The permittee shall have his erosion control plan available at the site of the activity at all times. All
earthmoving activities shall be undertaken in the manner set forth in the erosion and sedimentation control
plan identified with this permit. Revisions to the plan shall be approved by the Department.
6. The erosion control measures and facilities shall be constructed under the supervision and competent
inspection of an individual trained and experienced in erosion control, and in accordance with plans, designs
and other data as herein approved or amended, and with the conditions of this permit. Control facilities shall
be frequently inspected to insure effective control.
7. When the herein approved erosion control measures and facilities are completed, the permittee shall notify
the Department so that an inspection of the measures and facilities may be made by a representative of the
County Conservation District.
8. No storm water, sewage or industrial wastes not specifically approved herein, shall be admitted to the erosion
and sedimentation measures and facilities for which this permit is issued, unless with the approval of the
Department.
9. Sediment shall at no time be permitted to accumulate in sedimentation basins to a depth sufficient to limit
storage capacity or interfere with the settling efficiency thereof. The sediment removed shall be handled and
disposed of in a manner that will not create pollution problems and so that every reasonable and practical
precaution is taken to prevent the said material from reaching the waters of the Commonwealth.
10. All slopes, channels, ditches or any disturbed area shall be stabilized as soon as possible after the final grade
or final earthmoving has been completed. Where it is not possible to permanently stabilize a disturbed area
immediately after the final earthmoving has been completed or where the activity ceases for more than
20 days, interim stabilization measures shall be implemented promptly.
11. Upon completion of the project, all areas which were disturbed by the project shall be stabilized so that
accelerated erosion will be prevented. Any erosion and sedimentation control facility required or necessary
to protect areas from erosion during the stabilization period shall be maintained until stabilization is
completed. Upon completion of stabilization, all unnecessary or unusable control measures and facilities shall
be removed, the areas shall be graded and the soils shall be stabilized.
•*%.
12. The responsibility of carrying out the permit conditions shall rest with the owner, lessee, assignee or other
responsible manager of earthmoving that affects the approved erosion controls. Such responsibility passes
with each control succession.
C-844
-------
I. EFFLUENT LIMITATIONS AND MONITORING REQUIREMENTS, OUTFALL 001
WHICH RECEIVES WASTE FROM:
LAT
LONG 79°47'56
a. The permittee Is authorized during the period from issuance date
through expiration date
b. Based on the production data and anticipated wastewater characteristics and flows described In the permit application
and its supporting documents and/or amendments, the following effluent limitations and monitoring requirements apply:
Discharge Limitations*
Monitoring Requirements
Discharge
Parameter
Flow (MGD)
Total Suspended
Solids
Oil & Grease**
Aluminum
o
oo Dissolved Iron
Cn
Mass Units (Ibs/day)
Average Maximum
Monthly Daily
0.205
51.3
Concentrations (mg/1)
Average
Monthly
30
15
4
Maximum
Daily
Instantaneous
Maximum
60
30
8
7
4000 m°s/kg*
N/A
N/A
Measurement
Frequency
Daily
1/week
Sample
Type
Measured
8 hr comp
Grab
8 hr comp
24 Hour
Report
Under
A.3.C?
Osmolality 4000 mus/kg* 1/6 months f'8 hr comp
TDS N/A N/A N/A N/A N/A I/week
Chlorides N/A N/A N/A N/A
k
** The test method shall be equal to Method 503B, Standard Methods 15th Edition, or EPA Method 413.2.
pH Not less than 6.0 standard units nor greater than 9.0 standard units at all times. Daily Grab
There shall be no discharge of floating solids or visible foam in other than trace amounts.
Samples taken in compliance with the monitoring requirements specified above shall be taken at the following locations(s):
Outfall 001
*Unless otherwise indicated, these are gross discharge limitations.
-------
Faculty Nam, /Location H diamni) DISCHARGE MONITORING REPORT (DMA)
Franklin Brine Treatment Corp. ,, M. ,,,,,,,
NAME . r - . (t-'.°L (A'A'7)
ADDRESS ~U-S' RT- 322 EAST
P.Oi. Box 728
Franklin. PA 16323
TACILITY
f AU1U10UO
PERMIT NUMBER
t
. „, _„„ cranberry Township, Venango oouncy FROM
LOCATION
MONITORING
YEAR MO
DAY
TO
UU1
OISCHAROC NUMBER
PERIOD
YEAR
MO
DAY
ruutt f^fj^jrutfcu
OMB No. 2040-0004
Expires 2-29-84
{20-21} (22-23) (.24-25)
(2627) (28-39) (.30-31)
NOTE: Read Instruction! before completing thl» form.
PARAMETER
(32-37) ;
1 1
Flow
Total
Suspended Solids
Oil & Grease
o
Jo'
^ Aluminum
I
Dissolved Iron
Osmolality
TDS '
X
SAMPLE
MEASUREMENT
PERMIT ;
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT ":
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT !
REQUIREMENT
SAMPLE '
MEASUREMENT
PERMIT.
REQUIREMENT
SAMPLE
MEASUREMENT
;-PBWMIT '
REQUIREMENT
SAMPLE
MEASUREMENT
•"'PERMIT ,
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT
REQUIREMENT
NAME/TITLE PRINCIPAL EXECUTIVE OFFICER
COMMENT AND EXRUA.N AT1ON OF" ANY VIOLATI
(3 Card Only) QUANTITY OR LOADING
(46-13) (S-t-61)
AVERAGE
*-:': . : :•"'
Vv 0.205
1
- - '"> ":-•- • .-••' ' --
• • '>;. •• ;" • .- - :-•:
V.:*:=5l.3^;!>
4
1
t
1
i
-
N/A
MAXIMUM
v
i
'-( '"'?•'•.**• -,'-• ''••
:;
'
i
f
N/A
UNITS
MGD
PPD
(4 Card Only) QUALITY OR CONCENTRATION
{JS-43) (46-}}) (34-61)
MINIMUM
-
'
N/A
AVERAGE
30
15
4 ,
-
N/A
MAXIMUM
, 60
, 30 ,
_
/', 6 ,
7
4000
N/A
AND AM FAMILIAR WITH THE INFORMATION SUBMITTED HEREIN AND BASED
ON M>
OBTAIN
IS TRC
N1FICA
TMC P
33 US
and nr
f INQUIRY OF THOSE INDIVIDUALS IMMEDIATELY RESPONS
ING THE INFORMATION. 1 BELIEVE THE SUBMITTED INF
•JT PENALTIES FOR SUBMITTING FALSE INFORMATION, t
DSSiBtLlTY OF FINE ANO IMPRISONMENT SEE IB tl.S.C 4
C 4 1 3 1 9 IPrnalti** undrr thr»r statute* may includr futr» up
IBLE FOR
DRMATlON
ARE SIG
M*~I i iniMn
^tlOHMi SIGNATURE OF PRINCIPAL. EXECUTIVE
UNITS
mg/1
mg/1
mg/1
mg/1
rto /
m°s/
kg
NO.
EX
62-63)
&1
:-i. •:;.
TELEPHONE
REOUENCY
OF
ANALYSIS
(64-68)
Daily
/week
» '
M
'••^/l%:.
/6
bonths
/week
SAMPLE
TYPE
(69-70)
Measure
8 nr
comp
Grab
8 hr
comp
Grarj:
wym
' :1:,«, -*
cotnp^
:;-'«i ..'
DATE
<'C>PE ' "— ' ' '
-------
APDR«»« -U.S. Route. 322 E»et
-P-uCV Boy 72"
• PA01015W —
oor
_E tankliiL, _EA 1 63 23
LocATKiN C^ffE^T ty "T<3Wisli±p7 TeriaTrgff -Comity
MONITORING PERIOD
- YEAR
FROM
MO DAY YEAR
TO
(20-21) (22-23) (24-21) (26-27)
PARAMETER
(32-17)
Chlorides
pH
o
i
CD - •< '
\
>
/
\
SAMPLE
MEASUREMENT
PERMIT •'
REQUIREMENT
SAMPLE
MEASUREMENT
; PERMIT - "
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT '• '$
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT "
REQUIREMENT
SAMPLE .
MEASUREMENT
PERMIT
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT
REQUIREMENT
SAMPLE
MEASUREMENT
PERMIT
REQUIREMENT
NAME/TITLE PRINCIPAL EXECUTIVE OFFICER
i
TYPED OR PRINTED
3 Card Only) QUANTITY OR LOADING
(46-33) (54-61)
AVERAGE
''•',' '•'
ig'B/A '"/P
i
;-'-;,;-
1
1
' •.;;•:• •;- ••'••"•-• ".. • .,
• ; • / • '. •
1
"-1;^ "•: '••• :-.
I
i
i
MAXIMUM
N/A
• '} 7- ''• "• '
' - '. ':. '_.,-.' • ' ,-• . ' .'f j
'- . /•••:• • " "' -,-•
';'..-'' ', " •:' "": ,•--•.
--.;-'• . ?;- :';::-:-. - -
-•";':-':-< :' ,.>-t '•'•:' '•-.
•" ' '•' "'^'f- ::-
UNIT*
(4 Card Only)
(Jt~4S)
MO
(28-29)
DAY
(30-31)
QUALITY OR
(46-53)
MINIMUM
Vf?'.r »/>.;>.
6.0
'•., ':.•• •''f'"'-'''^
-
kxpires 2-23-84
i
NOTE: Read Instruction* before completing this form.
CONCENTRATION
(U-61)
AVERAGE
;N/A ; ;
'.
-
-
'"
-
MAXIMUM
-N/A". ;-,-;>•;
9.0
:';-!^r;:;t';e'{|'
I CERTIFY UNDER PENALTY OF LAW THAT 1 HAVE PERSONALLY EXAMINED
AND AM FAMILIAR WITH THE INFORMATION SUBMITTED HEREIN, AND BASED
ON MY INQUIRY OF THOSE
OBT AIMING THE INFQR M AT1O
IS TRUE ACCURATE AND CC
NlFlCANT PENALTIES FOR $
THE POSSIBILITY OF FINE Afs
33 USC 1 1319 fPrnaltirt usu
and nr maximum tmprttonmrnt i
INDIVIDUALS IMMEDIATELY RESPONS
N 1 BELICVE THE SUBMITTED INF
SUBMITTING FALSE INFORMATION. 1
D IMPRISONMENT SEE IB USC 1
4tr thftf tlolulfl may includr fmfi up
' hrtu'ftn S monlAl and A \fartt.t
IBLE FOR
DRMATION
ARE SIC
u<-| i ipiKir.
fc^l;**?! SIGNATURE OF PRINCIPAL EXECUTIVE
OFFICER OR AUTHORIZED AGENT
UNIT*
Stand.
Units
NO.
EX
[62-SJ)
ly
fc
TELEPHONE
AREA
CODE
NUMBER
FREQUENCY
OF
ANALYSIS
(64-6S)
week :£
ily
•AMPLE
TYPE
(69-70)
1
Si'
*
DATE
YEAR
MO DAY
COMMENT AND EXPLANATION OF ANY VIOLATIONS (Rtlrrrnce all allachmtnlt hrrc)
fPA Form 3320-1 (Rev. 10-79) PREvoy<= -piTioN_TO BE__USED
(REPLACES EPA FORM T-4O WHICH MAY NOT BE USED.!
PAGE
OF
-------
ER-BWQ-15-Rev. 4/78
COMMONWEALTH OF PENNSYLVANIA
DEPARTMENT OF ENVIRONMENTAL RESOURCES
BUREAU OF WATER QUALITY MANAGEMENT
WATER QUALITY MANAGEMENT PERMIT
NO. JJ182201-U
A. PERMITTEE; (Name and Address)
Franklin Brine Treatment Corporation
Parkwest Office Center
Building One, Suite 5&0
Pittsburgh, PA 15275
B. PROJECT LOCATION
Municipality
County
Cranberry Township
Vpnango
C. TYPE OF FACILITY (For Industrial wastes;itype of establishment
Gas Well Brine Treatment Facility
D. NAME OF MINE, PLANT, AREA SERVED, OUTFALL NO
•. ETC,
5
1C
UJ
O.
(n
I
t-
ui
Plans For Construction Of:
Pump Stations: Sewer*
and Appurtenances
b.
Sewage Treatment
Facilities
I InduslriHl Wasins
X| Treatment Facilltia
d.
Mine Drainage
Treatment Facilities
D
Outfall & Headwall
f. | | Str
earn Crossing g.
D
Impoundment
N/A
The Discharge Of:
reated
b.
D
Untreated
Sewage
d. I | Industrial Wastes
3. Discharge To:
N/A
b.
Surface Water
Ground Water
Name of Stream to which discharged or drainage area in which groundwater discharge
takes place or impoundment is located.
4. The Operation of a Mine I I
Maximum Area to be Deep Mined
N/A
Acres
5. An Erosion and Sedimentation Control Plan
Project Area is Acres
F. THIS APPROVAL IS SUBJECT TO THE FOLLOWING CONDITIONS:
1. ALL CONSTRUCTION. OPERATIONS, PROCEDURES AND DISCHARGE SHALL BE IN ACCORDANCE WITH APPLICATION
NO. 6182201 DATED 11-17-82 ITS SUPPORTING DOCUMENTATION,
AND AMENDMENTS DATED 12~16-82, l~31-83 . SUCH APPLICATION, ITS SUPPORTING DOCUMENTATION All|
AMENDMENTS ARE HEREBY MADE A PART OF THIS PERMIT. i
2. CONDITIONS NUMBERED.
1. 3. 4. 5. 6. 7. 8. 9. KL11, 12, 13, 14. 17, 18 and;19
Industrial Waste
Al 1
THE
AMD CONDITIONS NUMBER.ED .
EROSION CONTROL STANDARD CONDITIONS DATED .
WHICH CONDITIONS ARE ATTACHED AND MADE PART OF THIS PERMIT.
-STANDARD CONDITIONS DATED-
1971
.OF THE
3. SPECIAL CONDITIONS DESIGNATED
WHICH ARE ATTACHED AND ARE MADE A PART OF THIS PERMIT.
G. THE AUTHORITY GRANTED BY THIS PERMIT IS SUBJECT TO THE FOLLOWING FURTHER QUALIFICATIONS:
1. IF THERE IS A CONFLICT BETWEEN THE APPLICATION ON ITS SUPPORTING DOCUMENTS AND AMENDMENTS AND THE
STANDARD OR SPECIAL CONDITIONS. THE STANDARD OR SPECIAL CONDITIONS SHALL APPLY.
2. FAILURE TO COMPLY WITH THE RULES AND REGULATIONS OF THE DEPARTMENT OR WITH THE TERMS OR CONDITIONS
OF THIS PERMIT SHALL VOID THE AUTHORITY GIVEN TO THE PcRMITTEE BY THE ISSUANCE OF THE PERMIT.
3'
LAW
PERMIT IS ISSUED PURSUANT TO THE CLEAN STREAMS LAW, ACT OF JUNE 22 1937, P.L. 1987 AS AMENDED 35 PA
icEcT,!!,^ AND/OR THE WATER OBSTRUCTION ACT, ACT OF JUNE 25, 1913. P.L. 555 AS AMENDED 32 P.S. ! 681 ET
ISSUANCE OF THIS PERMIT SHALL NOT RELIEVE THE PERMITTEE 'OF ANY RESPONSIBILITY UNDER ANY OTHER
PERMIT ISSUED
DEPARTMENT OF ENVIRONMENTAL RESOURCES
DATE July 19, 1985
BY
TITLE
APPUT4M1
-------
SPECIAL CONDITION PART II PERMIT
CABOT OIL & GAS APPLICATION #6182201-T1
A. Within six months after the herein approved waste treatment works are
constructed and placed in operation, the permittee shall submit to the
Department evidence of the efficiency and adequacy of such works in
treating the waste discharges from this establishment.
C-849
-------
C-850
-------
ATTACHMENT C: FRANKLIN BRINE
INFLUENT MANIFEST
C-851
-------
C-852
-------
(P'^iS7^^:
franklin brine
treatment corp.
P.O. Box 728, Franklin PA 16323
(814) 437-3593
MANIFEST NO.
4701
Permit Number: PA—0101508
1.
2.
3.
4.
5.
Generator (oil and gas lease owner):
Telephone: Bus. - i I
Mailing Address:
Lease Name/Location:
Type of Water:
Emergency
CONSIDERATION OF DISPOSAL OF FLUIDS CONFORMING HEREWITH, ON MY BEHALF AND ON BEHALF OFTHE LEASE OWNER/S ABOVE NAMED.
WE HEREBY REPRESENT AND DECLARE THAT THIS CONSIGNMENT OF FLUID IS FULLY AND ACCURATELY DESCRIBED AND CONTAINS ONLY
COMPONENTS AND SUBSTANCES CUSTOMARILY ASSOCIATED WITH THE ORDINARY COURSE OF OIL AND/OR GAS WELL DRILLING AND
PRODUCING OPERATIONS. ALL EXCEPTIONS ARE NOTED UNDER ITEM #10.
6. Generator Agent's Name (please print):
7. Generator Agent's Signature:
9. Generator Agent's Title:
10. Exceptions and Comments:
8. Date:
11. Transporter:
13. Mailing Address:
14. Truck Number: _
16. Trailer Number: _
ACKNOWLEDGEMENT OF RECEIPT OF FLUID:
18.
Driver's Name:
(please print): _
12. Telephone:.
15.
17.
Plate Number.
Plate Number.
19. Driver's Signature:
(Driver's signature certifies that items 1 through 19 are correctly answered to his/her best knowledge, information and
belief).
20.
22.
24.
Date:
Beginning Gallons:
Unloaded Gallons:
21. Driver's Initials: .
23. Ending Gallons: .
25. Sample Number:
CERTIFICATION OF RECEIPT OF FLUID:
26. Operator's Signature:
28- Tank No. Temp.
29- Comments: _____
PH..
27. Date:.
Cond
0853
-------
C-854
-------
Sampling Report
Investigation of Mark Resources Corporation's Hazlett Well No.
Venango County, Pennsylvania
September 4, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Appalachian Basin production sites developed by the
Pennsylvania Department of Environmental Resources at the request
of EPA. The list was transmitted via telephone to the EPA
contractor on July 25, 1986. Site selection from this list took
place during a telephone conversation on August 26, 1986.
Pennsylvania State officials preferred to list the possible
sample sites by operator, type of site, site name, and permit
number, as shown below. The EPA contractor had no interest in
the manner in which the particular sites were listed (by site
name, location, operator, permit number, API number, etc.) as
long as the site could be identified in detail upon selection.
Thus, the EPA contractor had minimal information which kept to a
minimum the amount of bias. No other information was known about
the sites on the list at the time of selection. Detailed
information was obtained only after selection of primary and
back-up sites. The list consisted of 26 Appalachian Basin
production sites:
Operator
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
Nat'l Fuel Gas
Nat'l Fuel Gas
Nat'l Fuel Gas
NBA Cross
Mark Resources
Mark Resources
Mark Resources
Mark Resources
Moody & Assoc.
Moody & Assoc.
Type Site
gas Kelley #1
gas Armstrong #2
gas W-Small #1
gas H-Snyder #1
gas D-Nelson #1
oil Hill #1
oil Hill #2
oil Hill #3
oil Hill #4
gas 5645
gas 5988
gas 5998
gas Culbertson #1
gas Levi #1
gas Hazlett #1
gas Burchfied #1
gas PE Deiter #1
oil S-2
oil S-3
Permit no.
37121
37121
37121
37121
37121
37121
37121
37121
37121
37085
37085
37085
37121
37121
37121
37121
37121
37121
37121
41409 00
41152 00
37577 00
41396 00
41311 00
41020 00
41021 00
41022 00
41023 00
20038 00
20068 00
20113 00
37387 00
36991 00
39794 00
38214 00
35078 00
32937 00
32938 00
C-855
-------
20.
21.
22.
23.
24.
25.
26.
Moody &
Moody &
Moody &
Moody &
Moody &
Moody &
Moody &
Assoc. oil
Assoc. oil
Assoc. gas
Assoc. gas
Assoc. gas
Assoc. gas
Assoc. gas
S-4
S-5
S-6
S-8
S-9
S-12
S-13
37121
37121
37121
37121
37121
37121
37121
32939 00
32940 00
32941 00
32943 00
32944 00
38999 00
39000 00
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
No. 15 on the above list (Hazlett No. 1) was selected as the
primary sample site. No. 10 on the above list (Nat'l Fuel Gas
5645) was selected as a back-up site should sampling at Hazlett
No. 1 prove inaccessible or inappropriate. A second back-up site
was selected as a precautionary measure. No. 24 on the above
list (Moody & Associate's S-9) was selected as a second back-up
site.
No problems were encountered in arranging sampling of Hazlett No.
1 September 4, 1986. The back-up sites were not required.
Site Location
Hazlett Well No. 1 is located 5 miles north of Cooperstown, PA on
Sugar Lake Road. Figure 1 is a map indicating the site.
The site is operated by Mark Resources Corp., whose mailing
address and telephone number are:
Penn Center West
Building II Suite 224
Pittsburgh, PA 15276
412-788-1340
Attendees
Sampling of Hazlett Well No. 1 was performed by CENTEC
Corporation personnel on September 4, 1986. The following is a
list of people present at the time of sampling:
CENTEC Corp. (sample team):
Operator Representatives:
American Petroleum
Institute Representatives;
Bruce Hoskins, Team Leader
Jim Kourmadas, Technician
Matthew Vavro, Assistant
Production Superintendent
Mel Miser, Production Manager
George Holliday, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
C-856
-------
Figure 1. Location of Hazlett Well #1, Venango County,
Pennsylvania
C-857
-------
Site Description
Hazlett Well No. 1 is located in the Appalachian Basin, in a
rural foothill area; the depth to groundwater is 120 feet, and
the nearest surface water is 200 feet away- There are two
drinking water wells within a 1/4-mile radius of this site. The
soil in this area is mostly rock. The climate at this site
location is net precipitation.
This site is an actively producing gas well with production of
100,000 bbl per day of natural gas liquids and 2 bbls per month
of water. It is one of two wells on its lease. Production at
this site is sweet. The well depth is 5,500 feet. The well is
producing using natural drive.
Photos 1 and 2 (in Attachment A) show the facility in its
entirety. The site consists of a 100 bbl brine tank and a gas
well head. The brine tank has never been cleaned. No biocide
has been used at this facility. Production was enhanced by
fracturing stimulation on 12/84.
Disposal Practices
Brine is disposed by trucking it to a reinjection facility in
Ashtabula County in Ohio owned by Universal Energies. There are
no other wastes associated with the well.
Permits
The permit for the lease (No. 37-121-39749) is shown in
Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Location
The samples collected at Hazlett Well No. 1 consisted of two
liquid samples. The sample collection point was the brine tank.
Sampling Methods and Equipment
The samples were collected with the sampling thief from the top
of the tank through a thiefing hatch. This hatch is shown in
Photo 3. The produced water was tested onsite for pH and free
chlorine content after the completion of sampling. The pH of the
water was 7. Free chlorine content was less than the lowest
detectable level of 0.2 ppm.
C-858
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-859
-------
C-860
-------
Photo I. Well head and brine tank
O
I
CO
CTl
Photo 2. Well head and brine tank
Photo 3. Sampling hatch on top of brine tank
-------
C-862
-------
ATTACHMENT B: PERMITS
C-863
-------
C-864
-------
1: B«,. 4/83
COWMONWEALTH OF PENNSYLVANIA
DEPART. IT OF ENVIRONMENTAL RESOURCES
BUREAU OF OIL AND GAS REGULATION
1205 Kossman Building, 100 Forbes Avenue
Pittsburgh, Pennsylvania 15222
DER OFFICE USE ONLY
I.D. No:
Check No
&-*u
CKC-12967
9233
M.E:
1 Amc S50f
--- G:M
Lease t: 37-121-054
(1) MAttl
(9.) 'Peru
•Pit
-- •"' (See rerene lid* for lane Item Explanation) '""'"
^-NOTICE OF PROPOSED OR EXISTING WELL LOCATION w-£--| v ..n: rf-j:r!w ni (•.•>••» 10 .ri-ii.'o'"'0*' 9PeJ*?9r>Les?e*' or-0wne* '- -".H '° i"
n rVm-nr lto«t-/WiTt1H1"v': si "**' r '' ''*' nr ^ ;" li:""J '"'
City and State
'9 .;• ,: .. .i ..Zip Code oijrjuq? t no eh6; I'Gtyiand State"'-' nsi9-;mur. -.
2p Code -.M
17
H/A1J .1 "H— n I) ='--
Telephone No.
(7) '--r. 'Wa*1»f»- -"'- '-'
(8) ' Wen Farm No.' ' " ' 'ffl
Date
.:'''L.i,Jl' ' -o <-.
(9)' Se'rlii'No." f!s~"
County <•/•>" •:">1(JJ 'timni. wo!
VJ.-F.™** n-^oJi v-if/A-i -r
;i .'id;. ^fiinotJio.ioDs, ^ Qty'-iu
Coal Operator, Lessee,
ad lie* LiniK:Address-:v
Titqr- it1 ::o :ib:iu-.".- c
id State ' - ":- ' -
or Owner
l. ol— i.-c-j.o I!:!-
T -"iif « ijnrir.
Zip Code
ne:.; New Wefljg .;.:;;':^-'.';;, r \- -;;_
Drfll Dee'per (Existing WeU) D "
.Re-drfll (Existing.WeU) O_ ,
Storage Reconditioning (Existing Well) D
a. If existing well drilled after February of 1956, give
permit number '- _J " '
b. If existing pre-act unpermitted well, give date drilled
(13) N/A
_„
W/A
,., (14) W/A _ '
'"" "" :'' '"''''"' "'° '1"J'^'"J ..... "UL'J ^'- ::
Name of Gas Storage Reservoir
r^'iv.- ;i!r i-niou! niv a.jn. •
;io -!-jtf., h..-o-9 Jor i ;-',3::i
N/A
K/A
Storage Operator' -''
>~-. Address
CJty-aniState,, ...,-; -^^i.u .,-.. •,„. ; ZipjCpde;, ,,;,,
(16)WH1 well, penetrate • workable -eoal? .O- Yes Si NOBS.- !«_• ?:' (21).Antidpatea-;ty4>e .of i-weU (on, gas,
(17) Wm well be drilled at'a 'location where the rn»rW'h^K?!--" (My A-nri^pJfa 'tnt«rifepth '•*••-•' S'.'
' •
removed? D Yes n No (23) Wffl* you move" earth? &Yes D No "if yes, do you have
(18) WiH wen be covered by the Oil and Gas-Conservation Law? it* :L,J-- an 'erosion 'and'sedimentation control plan? gjYes D No'
bSfXff Ri.1*?-.;. n-isri.- £vat .:•-'• srt- !,jr,:?nsq ri'.-:;:',- zlisv-- oj ,U-Bo, refer to Line.Item Explanation #23 onjeverse side.,
(19) If answer to.(18)'is..yes, does location,ian-within an area^ .(24) ;WniweD_.penetrate or be -within J.-OOO/of an active gas
covered by a spacing order? D Yes g No .b-.rr.ws sti K.v;i»torage reservoir? D Yes.Sl.No ,.-:: 05 "'dcvL: ^;
(20):Is well part-of a project? D, Yes ^ JJo. -(--.-,.•: ori, '.o s HiO ?..*nSW!r,:?f ^io!T!?le^:.B?? ;£3J, "^f^g.^-S (PI)
If yes, give jnoject^ number_. . . ^ . . . .^^, , ^ ^. . ,,_,., ?° ,..
(25) The undersigned well operator is entitled to drill upon the above named farm having fee title thereto, or as the case may
be under grant or lease dated Jqnuar7 13 19 ^ymadeTiv 'co'rnid'^Tic'Dtrvoil' '^g'jj' ' - ' 'J' "»nri recorded on'
the iQtfr day of Fobrunry _ ^ -W*11 tne °ffice of the Recorder of Deeds for said county in- Book '
-363- > and subsequently^ assigned to Hark Resources -Corporation on August 4,^1983 cand-
- This notice, ^and the enclosed well location map, are herewith submitted to serye-«ottee by certified mail to the owners and lessees of
-any and all workable'coal seams'and to the owners and operators of any «cti*e gas storage reservoirs the proposed well locations will
• penetrate or be within 3,000' thereof. Such notice is to be forwarded by theiDmsion of/Permitting. .•
recorded eiR%Pf%^i@5EW>L^983 ^ Book 839«
Copies of notice and plat we're forwardeflf to 'above listed
coal and/or gas storage operators, owners, lessees on
ad 03 21 iiav 11 iit'i/oic; eaitqj sri3 ni noiiAirno^nJ jn:
,S.-: :s53Qt! .• r'l.agnafure/if.Well Operator or Authojtted Representative.:
.Tohn A. Rr*!go, JTr. Vice President of Ooerations
.lojb. :.:£•_•; i.. i.^sn. Print or type name of signer and titie ::i "• '• "•-;
(27) 'Service 'of^a copy: of: this notice and wen looitionnmap:upon'thelinndeisignedc'ls'iherebyl acknoiriedged'and'the'well'locatlon'
'^''•approved' this " L d»y nf ' ' ^ L ^' L 19~ " -"I'1 •* "g".' '• L " \" l '.'*".•
(281 ' ' (29) ' '.:--;«.-' .-• n. — ..r,r.-..: --" ,- . - , ,.-
. -u... . „.. ...Gas Storage Operator or Owner .^ /r .,„., . . K_ Coal Operator or Owner , .,„, „,„
DER OFFICE USE ONLY
DRILLING PERMIT
:3iqn t»snori4U£ K>
IsoD lo nulsngiS (6!
<1AV! KOITAOOJ JJ3W
7HT
J^-^ T^^
' 9
ftffrnBTTuirhher^ _
?o 2T/iAuaai m YAjaa 383Jaa3/; ra Tjuaan jJiw EHOITAOIJ^IA oaruoaxa YJT^HOO'/J
This permit covering the well operator and well location shown below is evidence of permission granted to drill in accortJartcSwhrfl'i
the pertinent legal requirements subject to the conditions contained tierein^anel on the reverse hereof. Notification must be given to
th« District Oil and G*i Inspector of the date well drilling will begin at least 24 hours prior to commencement of drilling activities.
FWrnlt-'expirej '"•JJ" "fr-'V'^"- bns »Vmleg'driinng'«!-ieQmir«ncgd''pHnr tff'that^^e"mid^ir'b«ecuted'wTtri 'due'diligence'?ik
dti anff Gas"IrispeSor7^*^*—•3jo^t;>OT91 1°"' «"''•' «? I-"7 looisrij aoiisior/ ont jLT^sr snuins a«f. ;o no;jinno-j it-aiqx? :
j)*.'ioyiu ,j;iogx.i^ JuU.-pD oi bsjni sic uox ^sijjlidi£.-;oqa9i Isj'jf luoy jnibisjy;."^Stoiy-ouf vnc evsri uci.;.1!«yjllcn»q brtc z^r
BICHAKD A, POHD1105- "^"J" 'ks'binjul sd'J;rw tsismji ?c»r)] 3o nsdmun-«ao\(qf ^ bn* j^c^ffcbc ^A'.iLJIi |.-'_L lo
Box 2
Boulette, FA
16746
Tele: 814-544-7356
NOTE: Keep one copy of this permit posted at the drilling location.
., . For special conditions see attached requirements.
Chief,!
PEP,MIT COr
C-665
- VOID UNLESS VALIDATED
-------
C-866
-------
TEXAS
C-867
-------
C-868
-------
Sampling Report
Investigation of Exxon Company, USA's
Hawkins Field Unit Well No. 1210
Wood County, Texas
June 19, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Sabine/Tyler Basin drill sites developed by the Texas
Railroad Commission at the request of EPA. The list was
transmitted via telephone to the EPA contractor on June 11,
1986.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
Railroad Commission officials listed the possible sample sites by
operator and specific location. For simplicity of selection, the
list was transmitted using only operator names. Randomization
and site selection took place during the telephone conversation.
The list consisted of four drill sites in the Sabine and Tyler
Basins:
1. SMK Oil Company
2. Justis Oil Company
3. Exxon U.S.A.
4. Greenwich Oil Company
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 3 on the above list,
(Exxon U.S.A.). Justis Oil Company (No. 2 on the above list) was
selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
Further inquiry identified the primary sample site as Exxon
Company U.S.A.'s Hawkins Field Unit Well^No. 1210 in Wood County,
Texas. No problems were encountered in arranging sampling for
June 19, 1986. The back-up site was not required.
C-869
-------
Site Location
The Exxon Hawkins Well No. 1210 is located approximately 1 mile
north of Hawkins, TX via Highway 14 in Wood County. Figure 1 is
a map indicating the drilling site. The full name and mailing
address for Exxon is:
Exxon Company, USA
16945 Northchase Drive
P.O. Box 4697
Houston, TX 77210-4697
Main Office Contact: Mr. B. Logan Moore, Jr., Division
Staff Engineer, Regulatory
Affairs
Phone: 713-775-6304
Attendees
Sampling at the Exxon site was performed by CENTEC Corporation
personnel on June 19, 1986. Following is a list of people
present at the time of sampling:
CENTEC Corp. (Sample Team):
State Representatives:
Operator Representatives;
Bill Lane, Technician
Jamie Mclntyre, Team Leader
Jerry Mullican, Director,
Underground Injection
Control, Railroad Commission
of Texas (RRC), Oil and Gas
Division
Windle Taylor, Manager NPDES
Program, Underground
Injection Control, RRC, Oil
and Gas Division
Carl Nelson, Laboratory
Supervisor, RRC
Leslie Savage, Geologist, RRC
Frank Groves, Geologist, RRC
Randy Early, Kilgore District
Director, RRC
L. E. Wallace, Technical
Advisor, Houston Drilling
Organization
B. L. Moore, Jr., Division
Staff Engineer, Regulatory
Affairs
Marvin Myska, Senior Field
Superintendent, Hawkins Field
Greg Dodson, Production
Facilities Engineer
C-870
-------
JAS. 1 POLLOCK\
-3 :
MAM* *•* «•*••!• •••
Mtt fl«*»4Cfl* ••••
•«•*•
-------
American Petroleum Institute
Institute Representative: George Holliday, Contracted
Observer
Site Description
The Exxon site is located in a rural flatland. The climate at
this site location is net evaporation. The soil is described as
clay. The site is located over the Woodbine formation of the
Tyler Basin. Figure 2 is a survey of the exact location of the
hole.
The depth to the groundwater in the area is 58 feet. The nearest
surface water is a stream located 300 feet west of the site. The
only nearby drinking water well is located more than one mile
from the site.
At the time of sampling, the site consisted of one oil well and
one reserve pit. The drill rig had been removed from the site.
Work on the pipeline from the well head continued for the
duration of the sampling efforts. Figure 3 is an approximate
schematic diagram of the site, indicating the directions in which
photos were taken (Attachment A).
This site was a developmental oil drilling site. The well was
drilled into the Woodbine formation of the Tyler basin. The well
was permitted to a depth of 5,4'00 feet, and was actually drilled
to a depth of 4,868 feet. Drilling began on June 4, 1986, and
the well was completed June 9, 1986.
Drilling was accomplished with freshwater base mud. The
quantities of compounds used in the mud are summarized below:
Mud Contents Volume Used (Ibs)
Barium Sulfate (Barite) 5,400
Sodium Montmorillite (Gel) 10,700
Sodium Hydroxide 1,700
Ferrochrome Lignosulfonate 500
Lignite 600
Sodium Bicarbonate 100
Sodium Acid Pyrophosphate (SAPP) 50
One unlined pit was constructed onsite to provide temporary
storage of drill cuttings, residual drilling muds from the
circulation system, waste cement, and rig wash water. The pit
contents were piped from the drilling operation. The pit was in
use between June 4 and June 10, 1986.
The pit was designed to the dimensions of 45 x 220 feet (width
and length) and 5 feet deep, as shown in the plat provided by
Exxon, Figure 4. Figure 3 shows the measured dimensions obtained
at the time of sampling, based on the liquid level in the pit at
C-872
-------
. EXXON - CENTRAL DIVISION - i/IL ENGINEERING REPORT ON PROPi. D DRILLSITE
LOCATION: Hawkins Field Unit, Well No. 1210 STAKED: 4/25/86
FIELD: Hawkins
RESERVOIR: Woodbine
LOCATION CALLS:
30' E of WL
910' S of NL of the
E. W. Moore "A"
80 acre tract
1202' W of EL
2637' N of SL of the
Jas. Pollock Sur., A-449
COUNTY: Wood
PROPOSED DEPTH: 4900'
CLASSIFICATION: Oil
ELEVATION: 403'
(from Topo map)
SURVEY: Jas. Pollock
ABSTRACT NO. 449 LEASE NO. E-61058
APPROVED BY: G.J. Hermsen
STATE PLANE COORDINATES:
Zone: North Central
X - 2,706,730.92
Y - 355,129.31
•ff) —• JAS.
I. K M~~, »• V — \\ «V
«i I *• ->""i;* \" -."
W. PARKER A-449
H. E. WATSON
•" A-645 •'
DISTANCE TO NEAREST STRUCTURE: None apparent within 500'
DISTANCE TO NEAREST OCCUPIED DWELLING: None apparent within 500'
DISTANCE TO NEAREST TOWN: Hawkins is S 1.1 mi.
IS WELL LOCATED IN INCORPORATED AREA? No
ROAD MILEAGE TO NEAREST MAJOR HIGHWAY: F.M. Hwy No. 14 is W 0.7 mi.
ROAD MILEAGE TO NEAREST RAILROAD SUPPLY POINT: Missouri Pacific RR (Hawkins)
is S 3 mi.
DISTANCE TO NEAREST LEASE/PUBLIC ROAD: Lease road is SE 480'
IS ROAD HEAVILY TRAVELED? No
DISTANCE TO NEAREST BODY OF WATER: Creek is W 300' (approx.) flowing S
WATER SOURCE: Existing water well (See Pete Gibson for location)
DISTANCE TO NEAREST PIPELINE: None apparent within 300' (M-scoping difficult)
DISTANCE TO NEAREST AIRPORT: Hawk Ranch (pvt) Airstrip is NE 2.8 mi.
DISTANCE TO NEAREST POWER LINE: None apparent within 500'
OTHER ENVIRONMENTALLY SENSITIVE AREAS & DISTANCES: Very thick underbrush
FIELD BOOK REFERENCE: ET-4065 PAGE 2
CMM:jr
May 6, 1986
Figure 2. Map and Description of Well Location
C-873
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Figure 3. Schematic Diaaran of Drilling Site
C-874
-------
k
n
i
CO
^J
Ul
<;
Figure 4. Plat of Drilling Site
(Provided by Exxon)
-------
that time. The pit was constructed both above and below grade
due to an upward slope from southeast to northwest. The
southeast end of the pit, viewed in Photo 6 in Attachment A, was
built up above grade, and the northwest end, viewed in Photo 1,
was cut below grade. The depth of liquid in the pit was 2 to 5
feet, and the depth of the sludge was approximately 1 foot.
The operator stated that pit contents included estimated volumes
of 350 barrels of cuttings generated from drilling operations,
1,200 barrels of drilling fluids and rig wash water, 20 barrels
of waste cement, and a negligible amount of waste lube oil, which
entered the pit with the rig wash water. The operator also
estimated that the pit contained a total of 5,200 barrels at the
time of sampling. These estimates are low in comparison with the
measurements made by the sample team, which suggest that there
were approximately 7,600 bbls in the pit, assuming an average
depth of 3 1/2 feet (see Figure 3 for field measurements.
Tanks storing diesel on site contained roughly 2,000 gallons
prior to removal of the drilling rig.
The pit contents were tested by Exxon and by the Texas Railroad
Commission, for chlorides levels. Exxon reported a chloride
level of 142 parts per million, and the RRC reported 250 parts
per million. Figure 5 is a copy of a laboratory report on pit
fluid contents, ordered by Exxon, dated June 16, 1986.
Disposal Practices
At the time of sampling, the operator expected to dispose of the
fluid and solids from the reserve pit by hauling them to a land
farm where they would be spread out and disked into the ground.
The specific land farm had not been identified at that time. The
pit was to be backfilled and the area to be restored to nearly
its original state.
Permits
A copy of the drilling permit secured by Exxon for the Hawkins
Well No. 1210 is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix^
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Exxon site, the samples were defined as the supernatant
and solid contents of the waste material in the reserve pit.
C-876
-------
Gas Services, Inc.
P. O. Box 2029
Tyler, Texas 75710-2029
214-593-2535
COMPANY: EXXON, USA
LEASE: HAWKINS FIELD UNIT 1210
SAMPLE DATE: 6-12-86
TEST DATE: 6-16-86
PIT H20 SAMPLE
Na
Ca
Kg
X
fcr*
HC03
SO/
co3
f%
Total Suspended Solids
Total Dissolved Solids
Total Sloaeived Solids
Specific Conductivity
PH
Specific Gravity
P Alkalinity
H Alkalinity
Total Alkalinity
287.5
68
11.5
12.2
MC/L
320
20
96.2
10,202
998
11,200
1.050
8.35
1.00004
20
680
700
MIL
MG/L
MG/L
•
(Appears to be elay particles)
Figure 5. Laboratory Analysis of Reserve
Pit Fluid
C-877
-------
Figure 3 indicates the sample points from which the pit samples
were composited.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 3, and to locate the
center of each quadrant. The measured points were marked by
placing stakes along the sides of the pit to facilitate locating
sample points.
The sample points were accessed by boat. The boat was pulled to
the measured sample points via three ropes, as shown in Photos 4
through 7. State and company personnel volunteered to assist
with the ropes.
The first sample to be collected was the liquid composite. The
liquid from each sample point was composited in a 5-gallon
carboy, shown in the boat in Photo 4.
The reserve pit was then sampled for sludge. The dredge was used
to sample the sludge because the sludge was too liquid to be
retained by the coring device. Two full dredges were obtained at
each quadrant, yielding a total volume of approximately 5
gallons. Photo 6 shows the sample team taking a sludge sample.
The solids were composited in a steel bucket.
The pH of both the liquid and the sludge sample was measured
onsite after sampling was completed. The pH for both samples
was 7.
C-878
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-879
-------
C-880
-------
Photo 1. Northwesterly view of reserve pit
O
I
CD
CO
Photo 2. Liquid surface of reserve pit
Photo 3. Northeasterly view across reserve pit
-------
Photo 4. Liquid sampling In east corner of reserve pit Photo 5. Samplers preparing to sample sludge with dredge
O
I
CO
00
-------
Photo 7. Dredge sampling In south corner of reserve pit
Photo 8. Rinsing boat after sampling
O
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oo
u>
Photo 9. Pouring liquid sample
-------
C-884
-------
ATTACHMENT B: PERMITS
C-885
-------
C-886
-------
Ri ^ROAD COMMISSION OF TEtf J
OIL & GAS DIVISION
PERMIT TO DRILL, DEEPEN OR PLUG BACK
ON REGULAR LOCATION
IMIT NUMBER
301789
"NUMBER
42 499 31471
DATE OF PERMIT
5/02/86
FORM W-1 (dated)
5/01/86
l^OPERATION
DRILL
DISTRICT
COUNTY
ACRES
RATOR 257097
06
WOOD
10,591
NOTICE
EXXON CORP.
P.C. BOX 4698, RH. 571F
HOUSTON TX 77210
NO ALLOWABLE WILL BE ASSIGNED unless well protects
all fresh water sands with sufficient surface casing. Where
Commission rules do not specify surface casing require-
ments, contact the Texas Department of Water Resources
for depth to which fresh water sands must be protected.
District Office T«l*phon« No. :_.. ORA«.afl9 BLKO
SVYOJAS. POLLOCK
AB->449
'ANCE-- LEASE LINES
580 FNHC - 7C10 FNL
-SURVEY LINES
1202 FEL -
2637 FSL
- - NEAREST WELL ON LEASE
1482
NOTE THE CONDITIONS ON THE REVERSE SIDE. PARTICULARLY CONCERNING SPACING RULE CHANGE. IT
IS THE OPERATOR'S RESPONSIBILITY TO INSURE THAT THE PERMITTED LOCATION COMPLIES WITH THE
DENSITY AS WELL AS THE SPACING RULES IN EFFECT ON THE SPUD DATE. A RULE 37 AND/OR RULE 38
EXCEPTION WILL BE REQUIRED IF, BECAUSE OF A FIELD RULE CHANGE, THE LOCATION IS NOT IN COM-
PLIANCE WITH THE COMMISSION FIELD RULES ON THE SPUD DATE.
.0(5)
HIS PERMIT AND ANY ALLOWABLE ASSIGNED HAY BE REVOKED IF A CHECK TENDERED TO
HE COMMISSION ,1$ NOT HONORED.
HAWKINS
• > ,
~t.-i
THIS PERMIT SUBJECT TO THE CONDITIONS ON THE BACK OF THIS FORM.
THE OPERATOR SHOULD CONSIDER THE REQUIREMENTS OF THE NATURAL GAS POLICY ACT
OF 1978, AS AMENDED, (NGPA), AND APPLICABLE STATE OR FEDERAL REGULATIONS.
Based upon the representations made on the FORM W-1 and those made on any plat or plats filed therewith, it is believed that the
'Peration indicated, when carried out at that point which you have represented to be the location of the above designated Well, complies as of
he date thereof, with the provisions of the applicable spacing rule SUBJECT TO THE LIMITATIONS, IF ANY, SET OUT ABOVE. Compliance
'itti the applicable Commission spacing rule renders it unnecessary that you secure a special Commission permit to cover this indicated
'Peration at the location shown, the same being classed as regular.
PHONE1 DIRECT INQUIRIES TO: DRILLING PERMIT SECTION, OIL AND GAS DIVISION „..«.. ^T^r, ~.
(B15I AAH-ntA Capitol Station-r. U. urawer
012)445-1314 Austin. Texas 78711
-------
C-888
-------
Sampling Report
Investigation of Mobil's C. W. Belcher Lease
Production Facility
Talco, Texas
June 20, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Tyler Basin production sites developed by the Texas
Railroad Commission at the request of EPA. The list was
transmitted via telephone to the EPA contractor on June 16,
1986. Randomization and site selection took place during the
telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
Railroad Commission officials listed the possible sample sites by
operator and specific location. For simplicity of selection, the
list was transmitted using only operator names. The list
consisted of five production sites:
1. Hunt Oil
2. Amoco Production
3. Arco Oil and Gas
4. Mobil
5. Union
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 4 on the above list
(Mobil Oil). No. 1 on the above list (Hunt Oil) was selected as
a back-up site in the event the primary site was inaccessible or
inappropriate.
Further inquiry identified the primary sample site as the Mobil
Oil Company C. W. Belcher Lease Production Facility near Talco,
Texas. No problems were encountered in arranging sampling for
June 20, 1986. The back-up site was not required.
C-889
-------
Site Location
The Mobil C. W. Belcher Lease (01796) production facility is
located approximately 3 miles east of Talco, TX via highway 71 in
Titus County, and approximately 14 miles north of Mount Pleasant.
Figure 1 is a map indicating the production facility site. The
full name and mailing address for Mobil is:
Mobil Producing Texas and New Mexico Inc.
Nine Greenway Plaza-Suite 2700
Houston, Texas 77046
Main Office Ph.: 713-871-5351
Main Office Contact: K.K. Defenbaugh,
Environmental and Regulatory Engineer
Attendees
Sampling at the Mobil Oil C. W. Belcher production site was
performed by CENTEC Corporation personnel on June 20, 1986.
Following is a list of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representative:
Operator Representatives;
American Petroleum
Institute Representatives:
Other Groups:
Site Description
Bill Lane, Technician
Jamie Mclntyre, Team Leader
Roy Ottmers, Engineering
Technician, Texas Railroad
Commission, Kilgore Dist.
K.K. Defenbaugh,Environ-
mental and Regulatory
Engineer
E.G. Patton, Production
Supervisor
Larry McClanahan, Production
Technician
George Holliday, Contracted
Observer
R.B. Welch, Sales Engineer,
Petrolite Oil Field
Chemicals Group
The Mobil C. W. Belcher production facility is located in a
rural, piedmont area. The climate at this site location is net
precipitation. The soil consists largely of sand and clay.
According to the permit application for a large pit on site,
there are no drinking water wells within one mile of the site,
and no fresh water in the area (Attachment B). The average
chlorides content of the produced brine is described in the
permits as being 10,000 mg/1.
C-890
-------
lit
SITE LOCATION
MOBIL PRODUCING TX&NM.NC
A
GENERAL HIGHWAY MAP
TITUS COUNTY
TEXAS
' STATE DEPARTMENT Of HIGHWAYS
AND PUBLIC TRANSPORTATION
U.S. DePARTMENT Of TRANSPOffTATlON
1HKI1. MOHIUT A
Figure 1. Location of Mobil's C. W. Belcher Lease Production
Facility, Talco, Texas
C-891
-------
The site consists of one heater-treater, three free water knock
outs, two brine tanks, four stock tanks, five brine pits, and
three injection wells. One of the two brine tanks is used to
settle out solids and hydrocarbons, and the other serves as a
suction tank to two pumps that feed the injection wells. Photo 1
shows the brine tanks with signs in front indicating the presence
of H2S gas. Figure 2 is an approximate schematic diagram of the
facility, indicating the directions in which photos were taken
(Attachment A). Figure 3 is a plat of the C. W. Belcher lease,
showing the location of the pits and tankage in relation to the
injection wells.
Oil enters the production area from nine producing wells located
on the Lucy Blackburn lease as well as the C. W. Belcher lease.
Referring to Figure 2, the free water knock out (FWKO) closest to
the brine tanks receives the C. W. Belcher oil, the FWKO closest
to the stock tanks receives the Blackburn oil, and the FWKO
between these two is used to test the output of individual wells.
At the time of sampling, there were nine oil wells collectively
producing daily quantities of 400 barrels of oil and 6,000
barrels of produced water.
As stated in the pit permits located in Attachment B, the use of
the brine pits is "limited to collection of produced water prior
to disposal." Figure 4 is a drawing of overhead and side views
of the five pits, and Figure 5 is a more detailed drawing of Pits
B through E. The general purpose of the pit system is to receive
brine from the production system only when there is overflow from
the brine tanks, when tanks are being cleaned, or in the event of
an emergency. The smaller pits receive incoming brine from the
brine tanks, and provide for skimming oil and settling solids
prior to Pit A. The largest pit (A) is lined with 4 inches of
gunnite, and was constructed below grade with 2 feet of freeboard
above grade (Photo 2). Pit A is filled on an average of once per
week.
All tanks on the facility are cleaned once every 3 years. The
pits are cleaned every 5 years.
Disposal Practices
Produced brine is disposed of in three injection wells on the
C. W. Belcher lease, located as shown in Figure 3. The injection
wells are Nos. 3, 4, and 7. Brine that is released to the pits
on site is also eventually injected into these wells. Any solids
collected when tanks and pits are cleaned are buried at a
location on the lease, either at the production tank battery site
or at a well site.
C-892
-------
n
i
00
V£)
OJ
BRINE
PITS
N
D
B
X pumps to
injection wells
brine
FWKO- free water
knockout
HT: heater-
treater
'. brine
: oil
Figure 2. Schematic of Production Facility
-------
H.5 P1HTO
W.B Hinlon
Mobil Oil
JOHN LEVINS
A-S40
BEN. J. JONES
A-309
Hgryrevt tt el
W B Hinlon
3. WINN
A-$2 2
H Wilton
Euon
Mobil Oil- 1/2
C i ion-1/2
T
Urt. Lucy Blackburn
Ciaon
L.H.Wilton
Eiien
THOMAS CONNOR
A-137
jo
Uonnia Dry Soovi Co.
IMI ITAH O»Tt»»»
COUNTY Of MAXIMS
niOlli.i
-J U.» .M ^ .0.
>— • •< »U "*
-------
See
D
X7
MAX. LtQt/iO LfVfL -
1:3 ftoff 0*
o
4
£
10
II
12
II
U
"/
17
It
If
20
21
22
21
94
IS
2*
27
21
2t
M
II
12
11
15
Figure 4. Brine Pits on Mobil Production Site
(drawing provided by Mobil)
C-895
-------
r
L
I
\
\
j
o
Figure 5. Detail of Brine Pits (drawincr provided
by Mobil)
C-896
-------
Permits
Permit numbers for the five pits on site are P002372A through
P002372E. The issuing authority for all these permits is the
Texas Railroad Commission, Oil and Gas Division. Copies of these
permits are located in Attachment B. Permits for two of the
three injection wells on the lease are also included in
Attachment B. No permit was available for Injection Well No. 7,
but a copy of its Plugging Record was provided by the Railroad
Commission.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the C. W. Belcher site, the sample was defined as the fluid
leaving the two pumps that feed the injection wells on site.
Figure 2 indicates the sample point from which the fluid sample
was composited.
Sampling Methods and Equipment
As shown in Photos 3 and 4, the fluid sample was obtained through
a pipe that tapped the discharge line from one of the two
injection well feed pumps. The operator replaced a pressure
gauge with the sampling pipe to enable sampling at this point.
When the pressure gauge was replaced, the pressure read 53 psi in
the 4-inch diameter discharge line. The temperature of the fluid
in this line was approximately 130°F, as indicated on a meter in
the line.
The sample was collected in a 1-gallon glass jar, and composited
in a 5-gallon glass carboy (Photo 5). Immediately after the
CENTEC team was through collecting their sample, the operator
collected a quantity of sample from the same sample port.
The pH of the produced fluid sample was measured onsite after
sampling was completed. The pH of this sample was 8.
C-897
-------
C-898
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-899
-------
C-900
-------
Photo 1. Brine holding tanks
Photo 2. Easterly view of site across brine pit
Photo 3. BrIne samp I I ng
Photo 4. Brine sampling
-------
Photo 5. Pouring liquid composite
Photo 6. Southerly view of brine tank (left) and
pump ( center )
O
I
to
"CJ
r^r.,s.« jo-'*-; ~
A*.
:;£=-.*•£&
i ??^,-:.r^V--; •:•%? Xi^^i
>&^3i«^r»!-t^hf=.'t ~ .-
S*f-~=--<'-.->--v>i---:c
:--jfifi*>.i
-------
o
I
10
o
Photo 10. Westerly view of brine pit
Photo 11. Skim tanks ("pits") at east
end of brine pit
Photo 12.
Northerly view of brine tank (left), stock tanks
(In background), and FWKOs
-------
C-904
-------
ATTACHMENT B: PERMITS
C-905
-------
C-906
-------
RAILROAD COMMISSION OF TEXAS
OIL AND GAS DIVISION
BUDDY TEMPLE, Ch»irm»n
J. H. MORROW, P.E.
JAMES
MACK
1701 N.
E. (JIM) NUGENT, Commiuioner / yj£->
WALLACE, Commiuioner :'W/«rW
:X A- /
\
-------
Permit No. P002372A
Page 2
7,
If the leak detection system indicates pit failure, the pit must be
inspected for deterioration and leaks within 5 days of detection of
pit failure. After inspection, the pit must be replaced or repaired
before resuming use of the pit.
8. The permittee must maintain a record of when the pit is inspected and
the results of each inspection. This record must be maintained by the
permittee for the life of the pit, and, upon request of the
Commission, the record shall be filed with the Commission.
9. Unless otherwise required by conditions of this permit, construction,
use, and maintenance of the pit shall be in accordance with the
information represented on the application (Form H-ll) and
attachments thereto.
10. A sign shall be posted at the pit which shall show the pit permit
number in numerals at least one inch in height.
11. The pit must be dewatered, backfilled, and compacted within 120 days
of final cessation of use of the pit. Final closure of the pit must
be accomplished in such a manner that rainfall will not collect at the
pit location after pit closure. Upon final closure, the
District Office shall be notified in writing.
12. This permit is nontransferable without the consent of the Commission.
Any request for permit transfer should be filed with the Director of
Underground Injection Control.
13. This permit does not authorize the discharge of any oil and gas wastes
from the pit.
This authorization is granted subject to review and cancellation should
investigation show that such authorization is being abused.
APPROVED AND ISSUED ON rfcvember 15, 1985
W. Mullican, Director
Underground Injection Control
C-908
-------
D New Appllcadon L/Cxo^O ' 9
0 Application for Renewal
AppL;o
RAILROAD COMiOSSJON Or TE.
Ol! end Cu DK-.«ler_
, for PcrniH to Mtinujn tais U»c c. Pit
Fonn H-l]
V.i-v l'^ir-4
ln«ruCTiOQj oo kjmcrae Ski
1 Opentof » Name (A« (tarn on Form P-S. Organization
Mobil Producing TX. & N.M, Inc.
6 Operator* Address (Street. City. State and Zip Cooel
Nine Greenway Plaza, Suite 2700
6 Name ol Lease. Project or Facility of Pit Location
C. W. Belcher Lease
8. pit Location
• iiff^iHffi *• 3 mi_ East
Report) 2. RRC Operator Ho. 3. RRC D
572550 fi
, Houston, Texas 77046
MPTM's Pit No.
6-7 (A)
Ben J. Jones
M.-^-tL^] i-™, Talco,
ML No. 4. County of pit aiu
Titus
7. RRC OU Lease No. or 8. RRC Ow ID No.
01706 !
Ah.-rw3Na.A- 309
Texas <„«„., ,r~^i
10. i. to pit bottom below (round
0Yes Quo
b Artificial Uner?
If lined, equipped with • leak dctecuon
Ye» No
11. Name and Addro* of SurCaoe Owner
Odel Belcher
Hwy. 71 East
Talco, Texas 75487
11 An waxes or Quid* from operation* other than
your own?
FxlYes PI No
13. Type of pit (refer to Item F of Inau-ucuom)
Collecting - Gunite 4" thick
14 a, Oe*crtbe land uae •uzroundln( ptt tocmdon:
Pasture
b. li land aurreundlnf ptt kxmtton praducttwe
afncultural land?
l&Pllta
0 Propowd
If cUMtng. dau eonatructed
IS. a. Brtcfly cxpUln the need (or thla pit
This pit will replace old unlined pit #6-1. It will be
used mainly for storage of salt water. Occasionally,
it will be used to collect salt water for short periods
of time.
15. b. Type of wmate or fluid: Salt Water
15. c, Chloctoe concentration:.
1Q.QQQ
18. Pit capacity (barrete)
5QQQ
7. Dikes
•. H«£ht abovf (round lewd .
. feet Width at bue .
116
19. Imfcie pit dimensions two feet below top of dike
Lenph 90 fact Width 90 fart
Depth:
feet
Yd [~| No
Yea No
from (round level la deepest point
b. Arc dikes designed to keep wastes or fluids In the pic?
c. Are dikes designed to keep aOrtnwaler runoff out of the pit?
d. Source of Dike Katertat 0 Excavated froen pit Q Adjacent borrow pit
\[ Off-alte excavatloo (describe materiaU
feet
30. WaMea or fluid* are transported to pit by (check aQ that apptyt:
£3 Contract Hauler [~| Applicant'* truck Fyl P«pt f~l Otner:.
21. a. Oucance to nearest water wefl
within one-mile of ptt
None t~.
21. b. Depth of thla water weO
None fa^
-22. Depth to «hallowe»< fresh water
feet
Source of information; No fresh water in area.
D
\\\ TDVr-R
23. Haw you inducted sJl attachments required by the Instructions on the
l?-iq-R4 Plus plaf. to show -- - - -
side of this form?
Yes (Prior subnittals of
R. R. C. OF
I oedarr under penalties prescribed tn Sec 9 1 .1
Reaourcea Code, that I am authorized to make
report wm» prepared by me or under toy superruton and direction.
and that data and beta stated there! n are true, correct, and emnptrte.
tothebestofnyknowfed^r. 0/G.
K. K. Defenbaugh, Env. & Reg. Engineer
Name of Person (type or print) Tlue
Telephone _ 713/871-5351 ^ October 14, 1985
KILGORE, TEXAS
Number
• RRC DtSTRJCT USE ONLT •
Application Information Review
(~^Acr>cultural Land
Grade Conatrueucm
[ *f Dimensions
Q^DUe.
Waste Traeaport
„ --
OBLY
C-909
-------
RAILROAD COMMISSION OF TEXAS
OIL AND GAS DIVISION
BUDDY TEMPLE. Ch.irmin
AMES E. (JIM) NUGENT, CommiMioner
MACK WALLACE, Commutioner
1701 N. CONGRESS
' &
£f?
'•
-------
Permit
Page 2
No. P002372B
7. If the leak detection system indicates pit failure, the pit must be
inspected for deterioration and leaks within 5 days of detection of
pit failure. After inspection, the pit must be replaced or repaired
before resuming use of the pit.
8. The permittee must maintain a record of when the pit is inspected and
the results of each inspection. This record must be maintained by the
permittee for the life of the pit, and, upon request of the
Commission, the record shall be filed with the Commission.
9. Unless otherwise required by conditions of this permit, construction,
use, and maintenance of the pit shall be in accordance with the
information represented on the application (Form H-ll) and
attachments thereto.
10. A sign shall be posted at the pit which shall show the pit permit
number in numerals at least one inch in height.
11. The pit must be dewatered, backfilled, and compacted within 120 days
of final cessation of use of the pit. Final closure of the pit must
be accomplished in such a manner that rainfall will not collect at the
pit location after pit closure. Upon final closure, the
District Office shall be notified in writing.
12. This permit is nontransferable without the consent of the Commission.
Any request for permit transfer should be filed with the Director of
Underground Injection Control.
13. This permit does not authorize the discharge of any oil and gas wastes
from the pit.
This authorization is granted subject to review and cancellation should
investigation show that such authorization is being abused.
APPROVED AND ISSUED ON November 15. 1985
W. Mull ican, Director
Underground Injection Control
C-911
-------
LJ New Application
LJ AppIlcaUon for Renewal
RAO-ROAD COMMISSION Of TEX. _
CHI uxi Gas Division
Application for Permit to Maintain and Use a Pit
.
Forml
I. Operator'* Name (A* ahown on Form P-S. Orfanlxauon Report)
Mobil Producing TX. & N.M. Inc.
2. RRC Operator No.
3. RRCDULHa
4. County of pit alte
Titus
3. Operator's Addrea* (Street. City. State and Ztp Code)
Nine Greenway Plaza, Suite 2700.
Houston. Texas 77046
6. Name of Lease. Prefect or Facility at Pit Location
C. W. Belcher Lease
MPTM's Pit No.
6-7 (B)
7. RRC OU
No.
01706
9. Pit London
I. 3
.Survey
East
Ben J. Jones
. (direction! Aram
Talco, Texas
AbatrartNa*_309__
-^—==— (nctrwi
10. a. U p4t bottom below (round lewd?
0Y«a Quo
b. Artificial taner?
[3 Ye* QNO
c If Uned. equipped wtth • teak detection *y*tetn?
0ve* QNO
11. Name and Addrea* of Surface Owner
Odel Belcher
Hwy. 71 East
Talco, Texas 75487
12. Are wastes or Quid* from operation* other than
your own?
13. Type of pit (refer to Item F of tiucrucuorwl
Collecting - Gunite 4" thick
C
14 a. Describe land use aurroundlnf pit location:
Pasture
b. It land surrounding pit location productive
agricultural land?
riYea fTlNo
16. Pit
15. a. Briefly explain the need (or thla pit
This pit will replace old unlined pit #6-1. It will '
used mainly for storage of salt water. Occasionally,
it will be used to collect salt water for short perio
of time.
Salt Water
S. b. Type ofwaau or fluid
S. c Chloride concentration:.
TO.OOP
.mi/I
If exl»Un(. date constructed
18. Pit capacity (barrel*!
178
7. Dike*
a. Helfht above (round level
. feet WMth at I
19. taatte pit dimenaloM two feet below top of dike
17 a,, ' mv4th 10 t^,
from (round bvd to deepeat point
fcet
fcrt
KArcdlkcadcaicncdtokeepwaaucorOuldalathcpIt? ED Ye» Q No
c. Are dlkea dealfned to keep atormwater runoff .out of the pit? _ |yl Yea F1 No
d. Source of DUx Material -ET1 Excavated trom pit Q Adjacent borrow pit
OfT^lle excavation (doolbc matertalk
30. Waste* or Quids are transported to pit by (check sO (hat appr/k
(^3 Contract Hauler Q Applicant'* truck (yl Pipe
Other.
31. a. Distance la nearest water wed
within one-mile of pit
None (_.
21. b- Depth of thla water wcfl
32. Depth to ahaBowect fresh water ^^___ feet
Source of information: No fresh water in area.
weC owner
Q electric lof
23.Kavevou Included aU attachment* required by the Instructions on the reverse side of this form?
12-19-64 Dins plat tr, show Tt^m 1 n-r c - ' -
Yes (Prior sutaittals
I dedarr under penalties prescribed In See. 91.143. texaj
Resources Code, that I am authorized to maT5c tH* @o£
repon was prepared by me or under my eupeWdonandtll
and that data and tacta slated therein are
U> the beat of ny anowledce.
K. K. Defenbaugh, Env. & Reg
Name at Person (type or print)
713/871-5351
Date
-------
RAILROAD COMMISSION OF TEXAS
OIL AND GAS DIVISION
lUDDY TEMPLE, Chairman ••''S^T~^C>'' ^ H" MORROW. P-E-
HMES E. (JIM) NUGENT, Commiwioner ^/f^'^'/^^K^''' Director
(ACK WALLACE, CommiMioner /W/$^Jt^hr; JERRY W. MULLIGAN
"•** • •^l.'.TV. x^ff^r F^I"W; ^
Director or Underground
Injection Control
""•• ... -••"
701 N. CONGRESS CAPITOL STATION — P. O. DRAWER 12967 AUSTIN, TEXAS 78711-2967
PERMIT TO MAINTAIN AND USE A PIT
Pit Permit No. P002372C
Mobil Producing Tx. & N.M. Inc.
Nine Greenway Plaza, Suite 2700
Houston, Texas 77046
Based on information contained in your application (Form H-ll) dated
October 14, 1985, you are hereby authorized to maintain and use the pit
designated herein:
Type of Pit: Collecting Pit
C. W. Belcher (01706) Lease, Pit #6-7 (C)
1200 feet FSL and 240 feet FWL of the Ben J. Jones Survey, A-309
Titus County, RRC District 06
Authority is granted to maintain and use the pit in accordance with
Statewide Rule 8 and subject to the following conditions:
1. Use of the pit is limited to collection of produced water prior to
disposal. No other oil field fluids or oil and gas wastes may be
stored or disposed of in the pit.
2. The capacity of the pit may not exceed 160 barrels.
3. At least 2 feet of freeboard must be maintained between the fluid
level in the pit and the top of the pit dikes.
4. The pit must be constructed of gunite at least 4 inches thick.
5. The pit must be equipped with a leak detection system to detect leaks
in the pit.
6. If the leak detection system indicates pit failure, the
District Office must be notified of that fact within 24 hours of
detection of pit failure.
m.^
3
-------
Permit No. P002372C
Page 2
7. If the leak detection system indicates pit failure, the pit must be
inspected for deterioration and leaks within 5 days of detection of
pit failure. After inspection, the pit must be replaced or repaired
before resuming use of the pit.
8. The permittee must maintain a record of when the pit is inspected and
the results of each inspection. This record must be maintained by the
permittee for the life of the pit, and, upon request of the
Commission, the record shall be filed with the Commission.
9. Unless otherwise required by conditions of this permit, construction,
use, and maintenance of the pit shall be in accordance with the
information represented on the application (Form H-ll) and
attachments thereto.
10. A sign shall be posted at the pit which shall show the pit permit
number in numerals at least one inch in height.
11. The pit must be dewatered, backfilled, and compacted within 120 days
of final cessation of use of the pit. Final closure of the pit must
be accomplished in such a manner that rainfall will not collect at the
pit location after pit closure. Upon final closure, the
District Office shall be notified in writing.
12. This permit is nontransferable without the consent of the Commission.
Any request for permit transfer should be filed with the Director of
Underground Injection Control.
13. This permit does not authorize the discharge of any oil and gas wastes
from the pit.
This authorization is granted subject to review and cancellation should
investigation show that such authorization is being abused.
APPROVED AND ISSUED ON November 15, 1985
W. Mullican, Director
Underground Injection Control
C-914
-------
3 New Application
3 AppHc«Uon fc
00 &\.
RAILROAD COMMISSION OF TDf
Oil and Ga* 1
Application for Permit to Maintain and U«e a Pit
Form H-ll
Mav 1&64
wtUi Instruction, oo fcrrcr»c Okie
"[ Opcntor'* Hunt (A* •nown on Form P-4. Orfwuzauon Report)
Mobil Producing TX. & N.M. Inc.
I. RHC Operator Ha
572550
3. RBC DM. No.
6
S~ODtntof* A4dn« (Suaet. City. Stale and Ztp Code)
wine Greenwav Plaza. Suite 2700. Houston. Texas 77046
4. County of pit attc
Titus
l or Fatality of Pit Location
"tl: c. w. Belcher Lease
MPTM's Pit No.
6-7 (C)
7. RRC Ofl Ua*e No. or a. RRC Ou ID No.
01706 *
g.pltLocaOon
• S*Ctl*a__
.Bfaek.
U
mile*.
.Surwy
East
Ben J. Jones
Abstract NO.
.(direction)
Talco, Texas
(nearcM town
.,
ft i to pit bottom brio,
c If toned equipped with « teak detection •yvtetn?
11. Naow and Addro* or Sutttec Owner
Odel Belcher
Hwy. 71 East
Talco, Texas 75487
• '2. Alt »Mlti or Quid* from operaciona other than
13. 7>pc of pit (refer us Item F of InMructlorM)
Collecting - Gunite 4" thick
4 «. DeKrtbe land uae aurroundlnf pit lorarlon-
( Pasture
b. I* land •urraundlnc P*( location productive
II.
!«• HI I*
Jls.
No
IS. a. Briefly explain the need (or thl* ptf
This pit will replace old unlined pit #6-1. It will be
used mainly for storage of salt water. Occasionally,
it wil.l be used to collect salt water for short periods
of tine.
S-b. Type of wa*«r or fluid: Salt Water
S.C, Chloride
10.OOP
If oa*dr<. date oon*tructed_
& Pit capacity (barrete)
157
j|9. ImUt pn dlmemtom two fact betow top of dike
r l*"Ch__15_fa« WVJth __LQ__ fart
Iroonround le»d «o caepcx point
T.Otko
a. Hri(rM abowr (round fe**i 2 (at Width mt baw
b. Are dike* dcalgned to keep wute* or fluid* la the pK?
c. AIT dike* deatfried to keep atamwaicr runoff out of the pit?
4 Source oT Dike Material Q Eunmied from ptt
O(F«nee«cavMloa(deaa1beniaterUlt
0. Wnte* or fluid* an tramported to pit by (check aO that apply*
'• D Contract Hauler fj Appllcanf* truck
II. a. Dttuncc to ntmrew water wd
•Uhlnoot-oukofplt
-__N°ne _- None
Other:.
21. b. Depth of Uu* water wdl I 2Z Depth to *haDowe*t (re*h witer
feet
a Have
12-1
Included an attachment* required by the Instructions on the rrverae aide of this form?
Plus plat to show Ttgm IQ-r K. ToaV
Source of information: No fresh water in area.
weflowner Q ekctrtc to< ^] TPWR
Yes (Prior submittals of
ccimncATB
I dtdarr under penaltle* pieaulued In Sec 91.143. Tea* Natural
toouree*Code that I am authorUed to make thl* report, that thU
report wa* prepared by me or under my *upervialon and dlrectloa.
•nd thtt dau and fact* Mated therein arc true, correct, and complete.
«• the beat of my knowMce.
K. K. Defenbaugh, Env. & Reg. Engineer
Name of Penan (type or prlntl TUte
Telephone
713/671-5351
October 14, 1985
• MtC DtSTWCT USE ONLY •
Application Information Review p r* —, ^
^ iij \^ V
B'Uner [fl
-------
RAILROAD COMMISSION7 OF TEXAS
OIL AND GAS DIVISION
8UDDY TEMPLE, Ch»irm»n
IAMES E. (JIM) NUGENT, Commi-ioner
HACK WALLACE, Commi»ioner
1701 N. CONGRESS
CAPrrOL STATION - P. O. DRAWER 12967
J. H. MORROW, P.E.
Director
JERRY W. MULLIGAN
Director of Underround
Injection Control
AUSTIN. TEXAS 78711-2967
PERMIT TO MAINTAIN AND USE A PIT
Pit Permit No. P002372D
Mobil Producing Tx. & N.M. Inc.
Nine Greenway Plaza, Suite 2700
Houston, Texas 77046
Based on information contained in your application (Form H-ll) dated
October 14, 1985, you are hereby authorized to maintain and use the pit
designated herein:
Type of Pit: Collecting Pit
C. W. Belcher (01706) Lease, Pit #6-7 (D)
1200 feet FSL and 240 feet FWL of the Ben J. Jones Survey, A-309
Titus County, RRC District 06
Authority is granted to maintain and use the pit in accordance with
Statewide Rule 8 and subject to the following conditions:
1. Use of the pit is limited to collection of produced water prior to
disposal. No other oil field fluids or oil and gas wastes may be
stored or disposed of in the pit.
2. The capacity of the pit may not exceed 160 barrels.
3. At least 2 feet of freeboard must be maintained between the fluid
level in the pit and the top of the pit dikes.
4. The pit must be constructed of gunite at least 4 inches thick.
5. The pit must be equipped with a leak detection system to detect leaks
in the pit.
6- If the leak detection system indicates pit failure, the
District Office must be notified of that fact within 24 hours of
detection of pit failure.
C-916
-------
Permit No. P002372D
Page 2
7. If the leak detection system indicates pit failure, the pit must be
inspected for deterioration and leaks within 5 days of detection of
pit failure. After inspection, the pit must be replaced or repaired
before resuming use of the pit.
8. The permittee must maintain a record of when the pit is inspected and
the results of each inspection. This record must be maintained by the
permittee for the life of the pit, and, upon request of the
Commission, the record shall be filed with the Commission.
9. Unless otherwise required by conditions of this permit, construction,
use, and maintenance of the pit shall be in accordance with the
information represented on the application (Form H-ll) and
attachments thereto.
10. A sign shall be posted at the pit which shall show the pit permit
number in numerals at least one inch in height.
11. The pit must be dewatered, backfilled, and compacted within 120 days
of final cessation of use of the pit. Final closure of the pit must
be accomplished in such a manner that rainfall will not collect at the
pit location after pit closure. Upon final closure, the
District Office shall be notified in writing.
12. This permit is nontransferable without the consent of the Commission.
Any request for permit transfer should be filed with the Director of
Underground Injection Control.
13. This permit does not authorize the discharge of any oil and gas wastes
from the pit.
This authorization is granted subject to review and cancellation should
investigation show that such authorization is being abused.
APPROVED AND ISSUED ON November 15, 1985
( ^Oerry W. Mull lean, Director
Underground Injection Control
C-917
-------
LJ New Application
LJ AppllcaUon for Renewal
RAILROAD COfcOOSSION Of TEX
OH and Ga* Dtvuton
Application for PcnnJt to Maintain and U*e a Pit Comply wtti
Form H-li
Mav
I. Operator i Mamt LA* •hewn on Form P-S. OryviliaUon Report)
Mobil Producing TX. & N.M. Inc.
2, RHC Operator No.
572550
9. RHC D«M. Ma
6
4. County of pit MM
Titus
S. Operator • Addrca* (StraeL Cl«y. S4au and Zip Code)
Nine Greenway Plaza. Suite 2700. Houston. Texas 77046
6. Name at \ (mtt Project or Faculty of fit Location
C. W. Belcher Lease
MPTM's Pit No.
6-7 (D)
7. RRC Otl Laaae No. or •. RRC Oai ID No"
01706 }
9. PK Location
• Sactta__
. Btoek
Ben J. Jones
. mflea.
East
. (dlracoon) from
Talco, Texas
10. a. to ptt bottoB below (round taiwf?
0Yea Quo
bArtAaalllner?
0 Yea duo
c If lined, equipped with • leak detection ayatetn?
OYO ["]NO
It. Name and AddraM of Suite* Ovncr
Odel Belcher
Hwy. 71 East
Talco, Texas 75487
12. Arc western or Ould* from operation* other than
your own?
13. Type at pit (refer to Item F of InatrucUon*)
Collecting - Gunite 4" thick
14 c Ooerlbe land UK •urroundlaf pit inrmnon
Pasture
b. U land •urroundlnf pK loeulon product**
16 Ptt
IS. a. Briefly explain the need far thtt pit
This pit will replace old unlined pit #6-1. It will be
used mainly for storage of salt water. Occasionally,
it will be used to collect salt water for short periods
of time.
15.6. Type o/wm«« or Bu»d: Salt Water
S. c Chloride concentration:.
10.000
IfexMlnc due
cted
18. Pn
17. Dike*
a. Hetcht above (round lewd .
. feet Width at boe
.feet
19. Inctde pit dlmrnMora rwo feet below-topef dike
Depth:
(root (round level to <
MpotiM.
6*
.faet
k.AredlkodeM(nedlokcepwaMaarfluki*l0(hepir? Ye» j_| No
c Arc dike* dealfned le keep MorBiwater runoff out of the pit? Q Yea Q Mo
d, Source of Dike Material: Q Eccmted from pit £] Adtaceot borrow pit
Off-allc excavation (describe aatcrtal):
20 WaMea or fluid* are tramponed to pit by (check aB that appr/k
D Contract Hauler Q AppUcanfa truck Q Pipe
21. a. OtMince to neareM water wefl
within one-mfe of pit
None «_ None
Other.
21. b. Depth of Uu» water wcfl
22. Depth to •haDoweal fmh water _____ feet
Source of information: No fresh water in area.
C3
Q weB
Q
TDWR
23. Have you included an attachment* required by the InatrucUona on the revcrme aide of thla form? (Prior S
12-19-64 Plus plat to show T1-gm IQ-r S. 1«.»k A*+ o^<-ion cy^tom Ami--r ^ *
cnmncATe
1 declare under penalUe* preaerlbed In See. 01.143. Tea* Natural
Re»ources Code, that I am authorized le make thl* report, thai thtt
rrpon wm» prepared by me or under my aupervlalon and direction.
and that data and (acts auied therein are true, cornet, and complete.
to the beat of taf knowledge.
K. K. Defenbaugh, Env. t Reg. Engineer
NameofPeraonltyptorprlntl ' Tuk
Telephone
713/871-5351
Ana Cede
Date
October 14, 198L
Dice
• KltC DtSTWCT USE ONLY •
Application Information ReMc»s
D
!0
OCT25T985
O.G.
C-918
-------
RAILROAD COMMISSION OF TEXAS
OIL AND GAS DIVISION
BUDDY TEMPLE, CKiirmin •f*&f.—^^i'- ^ H" MORROW. P.E-
JAMES E. (JIM) NUGENT. CommiMioner ;' M^^^^'-- Director
MACK WALLACE, Commi«ioner \^\^f'^^K^\ JERRY W. MULLIGAN
Director of Underground
Injection Control
JTOTN. CONGRESS CAPfTOL STATION — P. O. DRAWER 12967 AUSTIN, TEXAS 76711-2967
PERMIT TO MAINTAIN AND USE A PIT
Pit Permit No. P002372E
Mobil Producing Tx. & N.M. Inc.
Nine Greenway Plaza, Suite 2700
Houston, Texas 77046
Based on information contained in your application (Form H-ll) dated
October 14, 1985, you are hereby authorized to maintain and use the pit
designated herein:
Type of Pit: Collecting Pit
C. W. Belcher (01706) Lease, Pit #6-7 (E)
1200 feet FSL and 240 feet FWL of the Ben J. Jones Survey, A-309
Titus County. RRC District 06
Authority is granted to maintain and use the pit in accordance with
Statewide Rule 8 and subject to the following conditions:
1. Use of the pit is limited to collection of produced water prior to
disposal. No other oil field fluids or oil and gas wastes may be
stored or disposed of in the pit.
2. The capacity of the pit may not exceed 25 barrels.
3. At least 2 feet of freeboard must be maintained between the fluid
level in the pit and the top of the pit dikes.
4. The pit must be constructed of gunite at least 4 inches thick.
5. The pit must be equipped with a leak detection system to detect leaks
in the pit.
6. If the leak detection system indicates pit failure, the
District Office must be notified of that fact within 24 hours of
detection of pit failure.
C-919
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Permit No. P002372E
Page 2
7. If the leak detection system indicates pit failure, the pit must be
inspected for deterioration and leaks within 5 days of detection of
pit failure. After inspection, the pit must be replaced or repaired
before resuming use of the pit.
8. The permittee must maintain a record of when the pit is inspected and
the results of each inspection. This record must be maintained by the
permittee for the life of the pit, and, upon request of the
Commission, the record shall be filed with the Commission.
9. Unless otherwise required by conditions of this permit, construction,
use, and maintenance of the pit shall be in accordance with the
information represented on the application (Form H-ll) and
attachments thereto.
10. A sign shall be posted at the pit which shall show the pit permit
number in numerals at least one inch in height.
11. The pit must be dewatered, backfilled, and compacted within 120 days
of final cessation of use of the pit. Final closure of the pit must
be accomplished in such a manner that rainfall will not collect at the
pit location after pit closure. Upon final closure, the
District Office shall be notified in writing.
12. This permit is nontransferable without the consent of the Commission.
Any request for permit transfer should be filed with the Director of
Underground Injection Control.
13. This permit does not authorize the discharge of any oil and gas wastes
from the pit.
This authorization is granted subject to review and cancellation should
investigation show that such authorization is being abused.
APPROVED AND ISSUED ON November 15, 1985
/tjerry W.xMumcan, Director
^Underground Injection Control
C-920
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0 New Application
0 Application for Renewal
1 > £" RAILROAD COMMISSION OF TEX,'
' ^ OflandGi
Application for Permit to Maintain and Uae a Pit
AMENDE? '
FormK-11
Mty 1964
OB Rrrene
|. Operator'• NMpe (A* ahown on Pom M, OraanttaUoa Report)
Mobil Producing TX. & N.M. Inc.
2. M«C Operator Mo.
S72SSO
& MAC DM. No.
fi
4.CouB(jr«fpna
Titus
5 Operator's Aadrea* (Street. Ctty. State and Zip Code)
nine Greenwav Plaza. Suite 2700. Houston. Texas
77046
r. W. Belcher Lease
MPTM's Pit No.
6-7 (E)
7. KRC OH Leaae Ha. or •. KRC O«a ID No.
01706 !
•.PllUoaUon
Ben J. Jones
East.
Talco, Texas
(nearaat town
10. a to pM
(round tewet?
KAruaaalaner?
fjY« n*0
c If lined equipped with a leak detection cymteai?
Yea PI Ho
• 12. Air wwtes or Ouldc from opentton* other than
jfourown?
U *. DeKrtbe tand IMC •urrouadln( ptt Incartonr
Pasture
b. U knd «i(reundln( pK locmUon praduedW
•fncuirunl land?
tl6.ntM
II. Pit
:il9. iMlde pU dunra*«oa§ Mo fact below cep of dike
10 t-«
Depth: -: -
from ground le*d to deepen point.
.fact
11. Naaw and AddnH of SuriKx Owner
Odel Belcher
Hwy. 71 East
Talco, Texas 75487
13. Type of ptt (refer to Item F of InMrucuonal
Collecting - Gunite 4" thick
IS.«. Botfly explain the need (or thtt pa -
This pit will replace old unlined pit #6-1. It will be
used mainly for storage of salt water. Occasionally,
it will be used to collect salt water for short periods
of time.
Salt Water
lS.b.1>peof
S-e.Chk.rW
or fluid:
acute
1Q.OQQ •j/t
17.
idle
WWth*tl
•.Are dike* deaicned «> keep wMtei or fluid* ta the ptt? Y«§ No
cAredfla de^fned to keep Momwitler runoff out of the p«7 Q Yo* . Q *«
d. Source of CKke Matertal: tTI Exeavmted froai pn Q Adjacent borrow ptt
OflMlc eccMttoo (deacrtbe matertalk .- ; . - , . ^ •
jjJO. WtMa or fluid* are tranaported to ptt by (check an thaapor/t
D Contract Hauler Q Appttcanf* truch
II » DUuncr to neareM water wefl
within one-ffijk of ptt
' None c_ . None
Other.
21. b. Depth of du§ water weO
2X Depth to *hillii»i«> freah water . fcet
Source of buarmauarc No fresh water in area.
efaetrtclej
Yes (Prior submittals of
21 Haw you Induded aO anachmenu required by the InttrucUona on the iwcne aide of thla form?
12—1Q—fl^ Dlus nl/tt- t-rt eVii-iu T^am 10_r* C 1o«V <^ef'er>f'inn eve^-am /^aer-v 1*
cnrnncATB
I drdarc under penaftlea preacrlbed In Sec. fll.143. Tooa Natural
fcrnoureea Code, that I am authorued to otakc thla report, that thla
i^on waa prepared by av or under my auperotaian and dlracttoa,
and that data and (act* auted therein are true, comet, and eoeaplelc,
«• the beat of «qr knowledge.
tjflftJ
I/ Sialpaturc
K. K. Defenbaugh, Env. & Reg. Engineer
Name ofPeraon (type or prtnO o TMk
October 14, 1985
**-+-. 713/871-5351
Ana Coo*
• wtc DCSTWCT use
Application Information
EIVED
C. OF TEXAS
turmlUnd
n P
KILGORE, TEXAS
d.,e
-------
RAILROAD COMMISSION OF TEXAS
OIL AND GAS DIVISION
-«. «rv—-i • J. H. MORROW. P.E.
BUDDY TEMEtt Ch^rnun . • /*%&>>•*&&• DirMor
)AMESE-OI»^NUCENT.Com«i-ta-r £/$?bv5TW& JERRY W. MUU-ICAN
MACK WAU>CE, Co««l-lo«« ls(lT?F^]>] DH»c«r o< Und.rr.und
Inaction Control
imS 1H» - CAftTOL STATION - f. O. OMWER l»67 _ AUSTIN, TEXAS 7B711-iS*7
PERMIT TO DISPOSE OF OIL OR GAS WASTE BY INJECTION
INTO A POROUS FORMATION NOT PRODUCTIVE OF OIL AND GAS
PERMIT NO. 05052
bil Producing TX. & N.M. Inc.
ne Greenway Plaza, Suite 2700
uston, Texas 77046
sed on Information contained 1n your application (Form W-14) dated November 12, 1984,
Tare hereby authorized to dispose of salt water or other oil and gas wastes Into your
11 designated as follows:
C.W. Belcher Lease, (01706), Well No. 3
Talco Field, Titus County, RRC District 06
thority 1s granted to Inject Into strata in the subsurface depth Interval from .2634 feet
2736 feet at a maximum surface Injection pressure not to exceed 1300 psig, in
:o73ance with Statewide Rule 9 of the Railroad Commission of Texas, and subject to the
Mowing conditions:
1. A cement squeeze must be performed Immediately above the disposal zone.
2. Injection must be through tubing set on a packer. The packer must be set no
higher than 100 feet above the top of the permitted Interval.
3. The District Office must be notified 48 hours prior to:
a. running tubing and setting packer;
b. beginning any workover or remedial operation;
c. conducting any required pressure tests or surveys.
4. The wellhead must be equipped with a pressure observation valve on the tubing and
for each annulus.
5. Prior to beginning injection, and subsequently after any workover, an annulus
pressure test must be performed. The test pressure must equal the maximum
authorized injection pressure or 500 psig, whichever 1s less, but must be at
least 200 psig. ^ECr
Pnr
Form W-2 or G-l must be filed 1n duplicate with the District' FfrtcttF U£#)4S 30
days after completion or conversion to disposal. p£g „
** *M '« 00
The Injection pressure and injection volume must be monitored at, least monthly
and be reported annually on Form H-10 to the Commission's ALLS- Lin OrfiGe.
,
6. Written notice of the Intent to transfer the permit must be submlttta^Ki the
Director of Underground Injection Control at least 15 days prior to the date the
transfer will occur (File Form P-4).
vided further that, should it be determined that such Injection fluid Is not confined
the approved strata, then the permission given herein is suspended and the disposal
ration must be stopped until the fluid migration from such strata 1s eliminated.
30VED AliD ISSUED OH February 15.' 1985
3: Maximum surface Injection pressure 1s
ited to 1300 psig.
Jerry W. Mullican
Underground Injection Control
C-922
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HAIU<0;,I) COMMlMSIOM 0 !• TKXAS
OIL AND GAS DIVISION
)0H» H. POERRER. Chairman ....— _ «OB R. HARRIS Pf
MMES E IJIHI HUBERT. Commiwientr •''*j£z~^\'''- Chlt( En«'neer
KICK WAIUCE, Commis»ion«r , / */%£ , **§&': J. H. MORROW. P.E.
""'"* u ^M*' Assistant Chiif Enfinur
~ 5 |H „, CAPITOL STATION -P.O. DRAWER I Z907 • AUSTIN. TEXAS 78711
July 25, 1979
Mobil Oil Corporation PERMIT NO. 01528
Nine Greenway Plaza, Suite 2700
Houston, TX 77046
Gentlemen:
This will acknowledge receipt of your "Application to Dispose of Salt Water by
Injection into a Porous Formation Not Productive of Oil or Gas" (Form W-14)
covering your well designated thereon as follows:
C. W. Belcher (01706) Lease, Well No. 4, Talco Field, Titus County, RRC
District 6
Based on well completion data submitted on Form W-14 showing casing, tubing, and
cementing record, permission to dispose of salt water into this well is approved
by the Commission. It is required that the well be so cased and completed that
water can enter no formation other than the strata encountered at the depth
interval from 3200 feet to 3325 feet. It is required that the well be equipped
with an aboveground bradenhead observation valve. Maximum injection pressure is
limited to 800 psi.
Any permission to inject water into this well previously granted is herewith
cancelled and shall have no further force or effect. Upon' completion or con-
version to injection, Form W-2 must be filed in duplicate with the Railroad
Commission District Office.
In the event the well is presently carried on the proration schedule, you are
requested to notify the Commission in writing as to the date said disposal
operations commence. If the well is a dual (producing well and salt water
disposal well), you will be required to obtain multiple completion authority if
the injection string is part of the multiple completion. Further, Commission
District Office must be notified prior to any workover or remedial operations.
Notify the Commission District Office prior to running tubing and setting packer.
Yours very truly,
F- Singletary, Jr.
GFS:mm / Senior Engineer
u<_
cc: "RRC District - Kilgore
Proration - 6
Texas Department of Water Resources
C-923
fiftM/ ()/>/>•)/Minify /m/i/o
-------
Plucging Recnru
OIL AND GAS DIVISION
F«rm W-3
FILE IN DUPLICATE WITH DISTRICT OFFICE OF DISTRICT IN WHICH
WELL IS LOCATED WITHIN THIRTY DAYS AFTER PLUGGING
2. FIELD NAME (•• per RRC Record*)
3- LEASE NAME
l Numb«r
«. OPERATOR
MMIL OIL
10. County
Tim
7
11. Dele DrllHn,
/ Permit Issued
t. SURFACE LOCATION
FEET FROM
LINE. AND 3%t) FEET/fcfiOM UJcLL # S tW€
12. D.t, Drllllni
Commence
«. SECTION. BLOCK. AND SURVEY
13. Dstt DrilU.i,
Completed
IS. Type of Well (Oil, Gas. Dry)*
Stiff
16. Type of Completion (Single. Dual, Etc.)
SW&LE
17. Total Depth
14. Dele Well Plujjid
1-13-lt
I*. FORM W-l (Intention to Drill) Filed in Nan* of
19. Monner of Placement
PLUG »1.
PLUC »2
PLUG »3
PLUG •*
2.S
)O
. SACKS TOP.
SACKS TOP-
TOP.
TOP.
.BOTTOM.
.BOTTOM.
(o OO
.BOTTOM.
ID
.TYPE
-TYPE
.TYPE
.TYPE
30. W0( Well (ill.d with Mud-Ladm Fluid. YESg]
according to the reaulotions el the u/^ i — >
Railroad CommiisiSn N0
21. How wo« Mud applied?
33. Depth of Deepest [ 1*. Hor- ill Abandoned W.||5 YESTjQ
^ Fresh Wo>er an this Lease been Plugged ..-. £2.
fl/nfcX GO FEET ! according to RRC Rules? NO D.
22. Mud Weight
LBS/GAj
25. If NO. Explain
I 7<: Hone and Address of Parry Plugging Well
21. Casing and Tubing Record after Plugging
SIZE
10 ?S,, "
"7 '
— * •' -• ^F
PUT IN WELL LEFT IN WELL
FEET INCHES FEET INCHES
;2_^£> — P-f^c*
V?-3/ — •ri2-3 / —
\fi7 ft>P _ t-J-J/7_il ?-$?£> — 3-%1f£ —
*• C'J*^/f 9 ^ ^"> .«»
IP fU £tf,ffc,/l] • *> /_ ^-O ~- f^~J
It. Names and Addresses of Surface Owner of
! u)iLLisi/if BELCHM r
; U> . B • Ay//V7o// &oK i
i iWMELF DlLZXEFMi*
Well Site and Operators of Offset Producing Leases
fiL&o TEMS
'237 fy~T > iPL£J&/}t(}T 7£X/?£
V£ Co. P.p. tiDI 2*>Z£ TVLEJi TfX/te ~7S"7c>/
29. Was Notice given before Plugging ta each
i YES J§j NO r~]
"
of the above and RRC District Office?
D. li-
XAb
CERTIFICATE:
I declare under penaltu-s prescribed in Article 6036c. R. C. S., that I am authorized to rr.ake this repoi'..
that this report was prepared by me or under my supervision and direction, and that data and facis stated
thereip^etpje./correct. and complete, to the best of my knowledge.
" f
REPRESENTATIVE OF COMPANY
TITLE
Sl«nolure: REPRESENTATIVE OF RAILROAD COMMISSION
•All Dry Hole., Fill in Reverse Side.
C-924
-------
Sampling Report
Investigation of Murexco Petroleum, Inc.'s
Frye Lease Oil Well No. 1-29
Wheeler County, Texas
June 23, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Anadarko Basin drill sites developed by the Texas
Railroad Commission at the request of EPA. The list was
transmitted via telephone to the EPA contractor on June 11,
1986. Randomization and site selection took place during the
telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
Railroad Commission officials listed the possible sample sites by
operator and specific location. For simplicity of selection, the
list was transmitted using only operator names. The list
consisted of six Anadarko Basin drill sites:
1. David W. Slowson
2. Hober Oil and Gas
3. Dyco Petroleum Company
4. Murexco
5, Santa Fe Petroleum
6. Kaiser Francis
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 4 on the above list
(Murexco). No. 5 on the above list (Santa Fe Petroleum) was
selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
Further inquiry identified the primary sample site as the Murexco
Petroleum Incorporated's Frye Lease Oil Well No. 1-29, in Wheeler
County, Texas. No problems were encountered in arranging
sampling for June 23, 1986. The back-up site was not required.
C-925
-------
Site Location
Murexco Frye Well No. 1-29 is located approximately 6 miles
northeast of Wheeler, TX via Highway 152 and a county road 2
miles west of Highway 592 in Wheeler County. Figure 1 is a map
indicating the drilling site. The full name and mailing address
for Murexco is:
Murexco Petroleum, Incorporated
Glen Lakes Tower
Suite 1550
9400 North Central Expressway
Dallas, TX 75231
Main Office Ph.: 806-665-1653
Contact (Consulting Engineer): Mr. C.W. Kelly, Jr.,
President,
C.W. Kelly, Jr. Inc.
ph.: 214-368-2490
Attendees
Sampling at the Murexco site was performed by CENTEC Corporation
personnel on June 23, 1986. Following is a list of people
present at the time of sampling:
CENTEC Corp. (Sample Team):
State Representatives:
Bill Lane, Technician
Jamie Mclntyre, Team Leader
Jerry Mullican, Director,
Underground Injection
Control, Railroad Commission
of Texas (RRC), Oil arid Gas
Division
Windle Taylor, Manager NPDES
Program, Underground
Injection Control, RRC, Oil
and Gas Division
Carl Nelson, Laboratory
Supervisor, RRC
Leslie Savage, Geologist, RRC
Frank Groves, Geologist, RRC
Operator Representative:
American Petroleum Institute
Representative:
C.W. Kelly, Jr., President,
C.W. Kelly, Jr. Inc.,
Contractor for Murexco
George Holliday, Contracted
Observer
C-926
-------
a I 9 tot MI 12
BROOKS 9 BURLESON SUR.
LT.MU SITE LOCATION 3.f
Figure 1. Location of Murexco Petroleum's Frye Lease Well #1-29,
Wheeler County, Texas
C-927
-------
Site Description
The Murexco site is located in rural flatland. The climate at
this site location is net evaporation. The soil is described as
sandy loam. The site is located over the Granite Wash formation
of the Anadarko basin. Figure 2 is a survey of the exact
location of the hole.
The depth to the groundwater in the area is 50 feet. The nearest
surface water is a stream located 1/2 mile from the site. There
is one drinking water well located 1/4 to 1/2 mile from the site.
At the time of sampling, the site consisted of one oil well and
one reserve pit. The drill rig had been disassembled but was
still at the site, as shown in Photos 2, 3, and 6. The entire
area (approximately 210 x 350 feet) is fenced in. Figure 3 is an
approximate schematic diagram of the site, indicating the
directions in which photos were taken (Attachment A).
This site was an exploratory oil drilling site. The well was
completed at 12,500 feet. Drilling began March 20, 1986 and was
completed by June 13, 1986. Copies of weekly drilling reports
are located in Attachment C.
Attachment D contains copies of mud reports from March 20 to
April 23, when drilling reached total depth. Drilling was
accomplished with three fresh water base mads. These are
summarized in the table below:
Mud Type Depth Range (ft)
Pre-Mix 0 - 7,606
Low Solid Non- 7606 - 11,182
Dispersed (LSND)
Chemical 11,182 - 12,500
Details of the mud contents are available in the mud reports.
Lost circulation occurred three times during drilling. The first
volume of mud lost was approximately 200 barrels between 5,402
and 5,430 feet. The second lost volume was approximately 200
barrels at 6,195 feet. The final loss was approximately 150
barrels at 8,686 feet.
The drilling reports for May 1 and 2 describe the perforation of
the zone between 11,810 and 12,075 feet with a total of 84 holes.
Following this, the well received acidizing and fracturing
treatments, between depths of 11,950 and 12,066 feet. Copies of
the frac/acid logs are located in Attachment D. Details of the
acid and frac fluid contents are available in these logs and in
the drilling reports.
C-928
-------
PLAT SHOWING
PROPOSED NEW WILL LOCA )N
WHEELER
Dcicripiioh:-
1320' FNIL ft 1320' FWL
unty, Tttuu
29
SKIOO
A3
•lot*
K8G.N.
S—«r
N
MUREXCO
PETROLEUM
INC.
Tbit location hM DMA »«/y cjf«lully tufc«d on Uw ftound tccardlng
It IM bul oflicul tun*? ncoidt, m«p», end atvilng/intu e»«ile»U k>
ie* but to accuracy • not (uofantotd.
u» pl*l ond noiit» ut
Don
rn Patrol.>iiin Inc.
Topography &
Sandy, pasture
Reference Sraket or I —~~
Good Drill Sire? XfiS Alternate Location }
Siokci Set l_hUui
-Well No.:.
Belt Accetsibiltiy to
Oi:tuncc ond Direction
loctuan •*• Mimynd end luked on the pound u tnoon nw
~Zh -£' rJaaJi-
TWM Reg. No.
4159
TOPOGRAPHIC LAND SURVEYORS
430 Hue««« Hug.
reii
i TlObi
Figure 2. Survey of Well Location (Size of scale
has been reduced)
C-929
-------
"D
-------
One unlined pit was constructed onsite to provide temporary
storage of drill cuttings, residual drilling muds from the
circulation system, completion fluids, waste crude oil, and
miscellaneous trash. The pit contents were piped from the
drilling operation. The pit was in use between March 19 and June
13, 1986.
The pit was designed to the dimensions of 175 x 175 feet square,
and 6 feet deep. Figure 3 shows the measured dimensions obtained
at the time of sampling, based on the liquid level in the pit at
that time. The pit was constructed both above and below grade
due to a upward slope from north to south. The north end of the
pit, viewed in Photo 1, was built up above grade, and the south
end, viewed in Photo 2, was cut below grade. The depth of liquid
in the pit was approximately 1 foot, and the depth of the sludge
was approximately 2 feet.
Tanks storing diesel on site contained roughly 4200 gallons prior
to removal of the drilling rig. Approximately 20 gallons of
waste crude oil was generated by completion date. The waste
crude oil was disposed of in the reserve pit on site.
The pit contents were tested on June 20, 1986 by Murexco. At
that time the pH was 6.0, the specific gravity was 1.03, and the
chlorides content was 23,900 parts per million.
Disposal Practices
The fluid from the reserve pit will be vacuumed into a truck and
hauled to an injection well. The specific injection well was not
identified at the time of sampling. The solids in the pit will
be allowed to dry out for one year. The pit will ultimately be
backfilled and compacted.
Permits
Copies of permits secured by Murexco Petroleum Inc. for drilling
and ground water protection at the Frye 1-29 well are located in
Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Murexco site, the samples were defined as the supernatant
and solid contents of the waste material in the reserve pit.
C-931
-------
There was only one sample point where a discrepancy between the
actual and measured sample points was caused by the inaccessi-
bility of the measured point. This occurred in the southwest
quadrant of the pit where the cuttings pile was located. Figure
3 indicates the measured sample points as well as the actual
sample points from which the pit samples were composited.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 3, and to locate the
center of each quadrant. The measured points were marked with
stakes to facilitate locating sample points.
The sample points were accessed by boat. The boat was pulled to
the measured sample points via three ropes, as shown in Photo 5.
State personnel volunteered to assist with the ropes.
The first sample to be collected was the liquid composite. The
thief was used to collect this sample.
The reserve pit was then sampled for sludge. The dredge was used
to sample the sludge because the sludge was too liquidous to be
retained by the coring device. One dredge volume was obtained at
each quadrant, yielding a total volume of approximately 4
gallons. The solids were composited in the steel bucket shown in
Photo 7.
The liquid and sludge samples were tested onsite for pH after-
sampling was completed. The pH was 7 for both samples.
C-932
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-933
-------
C-934
-------
Photo 1. Southerly view of cuttings pile and
Photo 2. Northwesterly view across reserve pit
Photo 3. Northerly view across reserve pit
Photo 4. Attendees
-------
*-^ *•&
o
I
vo
u>
(Tl
Photo 5. Liquid sampling In northeast corner of
reserve p 11
Photo 6. Liquid sampling In northeast corner of
reserve pit
Photo /_ Filling sludge samplo jar- from sludge composite
-------
ATTACHMENT B: PERMITS
C-937
-------
C-938
-------
i-
z
E
.0.
UJ
•a.
t-
v-OEPTf — FUSABLEOUALITY GROUND WATER
PROTECTED
•*
The Information requested Is essentlel In order for this agency to provide an appropriate response, f lease allow !
our offices at least one week .before your operation begins. Due to the volume of these niaueiu. It It dif
Date
J-lfc-OU
J.N.
.^214/696-3463
Name of perionj>repering thit requett & Telephone No. w/AC
"wurexco Petroleum, Inc
^
y.
z
Company (operator's name «« on RRC form W-1)
Odin N. f.pntral EXDWBV. LE 178
Mailing Addreu
iDatlas
City and State
(.!•»!» Namp _ .
County . ,.
SreTiO" No,
TX 75231 ,
Zip Code
0
c
££
-------
R/" .ROAD COMMISSION OF TE)O
^ OIL & GAS DIVISION
PE
PERMIT NUMBER
299317
API NUMBER
42 433 31273
TYPE OF OPERATION
DRILL
RMI I 1U UnlLL, uccrciM un ruuu DML.IS. /Q /-r//, vj\
ON REGULAR LOCATION /£ A 4"- w
« CA-* 5
3/13/86
FORM W-1 (dated)
3/12/06
Vi 10 ^ &
-llShtfiRrvcet^7"
650
OPERATOR • 593997 --NOTICE
NO ALLOWABLE WILL BE ASSIGNED unless wsllpro
Miioevi PPTcni CUM. TUP "" freih water Mnds with tufficieni surfa" "*«*• «
nUKEJUj PS 1 KUCelln* iHW» Commission rules do not specify surface casino rsqi
9400 N« CENTRAL E fP* f 1S50~LB 178 ments, contact the Texas Department of Water Rssoi
DALLAS TX 75231 'or ^e"th *° wnicrl *r«ri water sands must be prom
' District Off ic* Telephone No. :
000 66?-lM3
LEASE NAME
FBYE
LOCATI.ON
6 HUES NE FRO* WHEELER
SECTION, BLOCK and/or SURVEY
SECO29 8LK«>A3
DISTANCE - - LEASE LINES
1320 FNL - 1320 FWL
WELL NUMBER
1029
TOTAL DEPTH
12*500
SVY->H £ SN AB->
--SURVEY LINES
1320 FNL - 1320 FWL
- -. NEAREST WELL ON LEASE
NA
NOTE THE CONDITIONS ON THE REVERSE SIDE, PARTICULARLY .CONCERNING SPACING RULE CHANGE. IT
IS THE OPERATOR'S RESPONSIBILITY TO INSURE THAT THE -PERMITTED LOCATION COMPLIES WITH THE
DENSITY AS WELL-AS THE SPACING RULES fN EFFECT ON THE SPUD DATE. A TUJLE '37 AND/OR RULE 38
EXCEPTION WILL BE REQUIRED IF, BECAUSE OF A'FIELD RULE CHANGE, THE LOCATION IS NOT IN-COM-
PLIANCE WITH THE COMMISSION FIELD RULES ON'THE SPUD DATE. - V " > *• ^
FIELD(S) • . , r- .„...., .....
THIS PERMIT AND ANY ALLOWABLE ASSIGNED MAT BE REVOKED IF A CHECK TENDERED TO
* THE COMMISSION 1S:NOT HONORED*
WILDCAT <--<---. - / V
** LIMITATIONS **
WILDCAT ABOVE 12,500 FEET.
REGULAR PROVIDED THIS WELL IS *EVER DRILLED DEEPER THAN 125DO FEET.
THIS PERMIT SUBJECT TO THE CONDITIONS ON THE BACK OF THIS FORM.
THE OPERATOR SHOULD CONSIDER THE REQUIREMENTS OF THE NATURAL GAS POLICY ACT
OF 1978, AS AMENDED, (NGPA). AND APPLICABLE STATE OR FEDERAL REGULATIONS.
Based upon the representations made on the FORM W-1 and those made on any plat or plats filed therewith, it is believed that
operation indicated, when carried out at that point which you have represented to be the location of the above designated Well, complies «'
the date thereof, with the provisions of the applicable spacing rule SUBJECT TO THE LIMITATIONS, IF ANY, SET OUT ABOVE. Complin
with the applicable Commission spacing rule renders it unnecessary that you secure a special Commission permit to cover this indi«
operation at the location shown, the same being classed as regular.
DIRECT INQUIRIES TO:
PHONE'
(612) 445-1314
DRILLING PERMIT SECTION, OIL AND GAS DIVISION
„ . , e .
C«pitol Stmon-P.
Austin, TiMJ 7B7H
C-940
-------
/^rnONK DATA ON WBLt COMPLETION AND LOG [Not Required on Rete*t)
V-^rfComplrtlon:
...--• • ••• — " TT3 —-•-—- — i~-j
-, , ,.,-', .. , .', NewWeD LSI Deepening LJ
1 - •
f rittloc of Intention to Drill thla well was Bled In Name of
^••itirexco Petroleum, .Inc.
Plug P*"!' 1 1 Other i I ;. /
- — •- --- --^,-«-- ••-- -•
11 'Hwnber of producing wells on thla lease In _.., .28. Total number of acres ^__
N'llitt flekJ (reservoir including this veil . - Jn this lease .'. ' -""-
|k:i~" ' - -
"i rkie Plus Back. Deepening i C
. WorkOver or Drilling .-(
2 ! 3"
'•;. [nation of well, relative to nearest
V of lose on which thla well la locate
i>i Elevation (DF. RKB. RT. OR ETC.)
i1 2326' GR
L lop of Pay 35. Total Depth
fc
II.QSO' 12,500'
i,,L U wed multiple completion? 39.
VII
n. No
\ Natw of Drilling Contractor
li)
if Petren Drl?.
3.
' CASU«JSIZE WT'/FT.
i' 13 3/8" 54.5
,'•
1 fi S/R" 32#
S 1 /?" 20//
Uunmenced | Complet
-H -•
-20-86 J4-25-8
lease boundaries I
36. P. B. Depth 3
12.331'
D3U -•
ed 30. Distance to nearest well.
i- Same Lease •* Reservoir
6 None
25. Permit to DrflL
Plug Back or
Deepen . -
•RuleS?
Exception
Water Injection
Permit
DATE PERMIT NO.
"3-13-86 299517
CASE NO.
PERMIT NO.
,,_ Salt Water Disposal - PERMIT NO.
•Permit
-Other " —
1320 'Feet From North Uneand
West Line of the Frye
33. Was directional survey made other i— i
than inclination (Form W— 121? 1 1 Yes
7. Surface Casing ^_^ ! T
Determined by Field [ | Recommendation of TD.WJt •
{Rules i Railroad Commission (Special 1 L
If multiple completion, list all reservoir names (completions In this we
or Gas ID No. GAS ID or
FIELD »» RESERVOIR OIL LEASE •
NA
01) and Oil Lease
OU— 0 WELL
Gas— G •
- -
"..-. - •• PERMIT NO.
1320 Feet from
Lease
|X| No
71
^ Dt. of Letter 3-14-86
_J ftt nf Ij-n^r
40. Intervals , Rotary | Cable
Drilled | Tools | Tools
. ^ i |
i •"• i
42. Is Cementing Affidavit
~| Attached?
Dl — I
Yes 1 — 1 No
CASING RECORD (Report All Strings Set in Well)
DEPTH SET
257'
3502'
12.505'
;k.
Size
TOP
MULTISTAGE TYPE «• AMOUNT HOLE SIZE 1
TOOL DEPTH CEMENT (sacks) C
— Cl "A" & "H" 17 1/2" Sv
200 sx
Cl ""A" 10 1/4"
2020 sx
Cl "H" C550 sx) 7 7/8" 10
LINER RECORD
Bottom Sacks Cement
POP OF SLURRY VOL.
EMENT cu. ft.
irface 313
3982.6
,550'
Screen
«. TUBING RECORD
Size
? 7 /a"
Depth Set
1 ? 331 '
Packer Set
11 R701
46. Producing Interval (this completion) Indicate depth of perforation
f™" Ilr950' - 11.956'
*•""" 11.960' — 11.966'
Fmm 11.970* - 11.973'
**» 11.9RO' - 11.987'
XX 11.992' -
28? 12.010' -
To
To
or open hole
12,001'
12.018'
•«7. ACID. SHOT. FRACTURE. CEMENT SQUEEZE. ETC.
Depth interval
11 Q^Qi _ 19 niH'
Amount and Kind of Material Used
117r200
acidized
sealers.
pals RXL-5. 237.000* 20/40 Ottawa Sd
: 3000 ?als 152 HCL acid w/126 ball
**L FORMATION RECORD (LIST DEPTHS OF PRINCIPAL GEOLOGICAL MARKERS AND FORMATION TOPS)
Formations
Cleveland
.Granite Wash
0.
Depth
' -10.500
11.800
Formations
^ . - .
'
Depth " —
i REMARKS
C-.9.4 1.
-------
C-942
-------
ATTACHMENT C: DRILLING REPORTS
C-943
-------
C-944
-------
MUREXCO PETROLEUM, INC.
MEEKLY DRILLING REPORT"
JUNE 6-12. 1986
FRYE ll-29/COMPLETION Murexcoh/Operator
5/heeler Co., TX MPI MI:
Sweetwater Creek Prospect 1986-A
6/6/86
BegaiTallowable tst G> 11 AM. SITP 950#, SICP 1450. Open to tank on 20/64" chk.
Gas vol. 340 MCF/D, flo'd 47 BO, 3 BW during 24 hr tst. G> end of tst - FTP 200#,
CP 700*. Well left flo'g to frac tank on 20/64" chk.
6/7/86
2004 FTP & 700# FCP. Flo on 20/64" chk, rec. 43 BO & no wtr in 21 hrs.
6/8/86
SI well Saturday 6/7/86 @ 6 PM.
6/9/86
6/11/86
84 hr SITP 2400#, SICP 2900#. SI.
6/12/86
107 HR SITP 2825, SICP 3100#. @ 7 AM: Opened well on 32/64" to 38/64" chk to keep from
freezing. Flo'd 38 BO in 1st 2 hrs, FTP 1000#, FCP 1500#.
C-945
DRLRPT/D 1
-------
C
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
MAY 30 - JUNE 5. 1986
FRYE n-29/COMPLETION Murexco/Operator
Wheeler Co., TX MPI WI:
Sweetwater Creek Prospect 1986-A
5/30/86
MI & RU Hootus 1st Unit w/1.0 MMBTU heater. Opened well on 6/64" chk (? 9 AM 5/30/86
SITP 3500*, SICP 3800*. (? 10 AM xflo on 10/64" chk, 3200# FTP 550/600 MCF/D. Flo some
liquid, mostly oil, no measurement yet.
5/31/86
SITP 35002, SICP 3800#. Opn well @ 9 AM, flo'g thru tst separator on 7/64" chk. Put o!
10/64" chk (? 11 AM w/3100# FTP & 3300# FCP @ rate of 1216 MCF/D. Press & rate dec thru"
out test period. This AM: Flo'g on 10/64" chk w/1825 FTP & 2150 FCP @ rate of 626 KCF1!
Rec. 152 BO & no wtr in 22 hrs.
6/1/86
Cont to flo well thru tst separator on 10/64" chk. Press & rate continue to dec but no''
as rapidly. @ 7 AM flo'g well on 10/64" chk w/1300# FTP & 1625 FCP @ 586 MCF/D. Recovl
121 BO & no wtr last 24 hrs. Cum oil recovered 273 bbl.
6/2/86
Cont. to flo well thru tst separator on 10/64" chk. Well appears to be stabilizii
Press & rate have remained constant last 12 hrs. @ 7 AM 925 FTP, 1500 FCP on 10/64" ct
6 rate of 473 MCF/d. Rec. 110 BO & trace of wtr. Total rec. 383 BO 13 BW.
6/3/86
24 hr flo rec. 76 BO, 3 1/2 BU, total fluids rec. 456 BO, 16 1/4 BW. Thurman McGlophlii
took recombined samples for analysis @ 3 PM 6/2/86. 1 PM sample to BJ for analysis:
Wtr - grav. 1.010, pH 5.8, Chlorides 40,270, Na 24,000, Ca 3000, Fe 150, Mg 640;
Oil 48.8 API.
6/4/86
"FTFon 10/64" chk w/725# FTP & 1350#. Press has remained constant & gas rate constant
last 24 hrs. Rec. 323 MCF/D, 58 BOPD, 1 BW/D.
6/5/86
Flo'd well on 10/64" chk w/avg. FTP of 675# & 1300# CP. Avg. gas rate of 300 MCF/D,
64 BO, 1 BW. Well press & rate has been fairly constant for last 60 hrs. Released
tst unit @ 7:00 AM.
C-946
DRLRPT/D 1
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
MAY 16-22. 1986
FRYE n-29/COMPLETION Murexco/Operator
Wheeler Co., TX MPI WI:
Sweetwater Creek Prospect 1986-A
5/16/86
Gas est. 50 MCFPD in 5 1/2" csg - no fluid. PU Baker junk basket & 4.520" G ring &
run on sd line to 12,150' touching nothing. POH w/J basket, 1 piece of metal in basket.
ND BOP, NU xmas tree. Start FL w/swb 5000', rec. 43 bbl in 2 hrs. Final FL 5200',
lOOi* psi on csg @ 7 PM. Gas before, during & after swb pull. 1596 BFTR. SI (=> 7 PM.
King Rig Released. This AM: 220# TP, 900* CP, 16/64" chk. Gas for 10 min & spraying
fluid & died. Swb'g unit on way.
5/17/86
12 hr SITP 220, SICP 900. Open on 16/64" chk - to 0 in 10 min w/dry gas, then flowed
spray of fluid (10 bbls) & died. RD King WO rig. MI & RU King swb unit. SICP 1000?,
FL @ 5000'. Rec. 82 bbls in 6 hrs, well flo'g @ 4 PM, CP 900#. Flo'd 31 bbls from 4 PM
to 7 PM. CP dropped to 650# @ 7 PM, 20% cond., 80% frac fluid, 12 hr rec. 123 bbls.
1473 BLTR, left flo'g on 3/4" chk w/flo crew.
5/18/86
Well flo'd 34 bbls in 12 hrs, CP dropped to 500# @ 1AM, tbg flo died @ 2 AM, CP inc. to
900* @ 7 AM. Start FL 4500', scattered to 9000'. Made 1 swb run rec. 5 BF. Tbg flo'd
13 bbls in 3 hrs, CP dropped to 500£, tbg flo died. FL w/swb @ 8500' & thinly scatted to
SN, 1 run/hr. Rec. 23 bbls in 7 hrs, 40% oil, 60% load. Gas meas. 360 MCFPD after swb
pull, gas meas 5 min after swb run 240 MCFPD, left tbg opn on 3/4" chk @ 6 PM, CP 500*.
5/19/86
Flo'd 9 BC overnite, tbg dead (? 7 AM, CP 10001. Start FL 4500' & scattered to 9000'.
Rec. 5 bbl on 1st run, flo'd 17 bbl in 3 hrs. CP dropped to 500#, tbg flo died @ 10:30
AM, FL w/swb @ 8500' & scattered to SN. 1 run/hr, 7 hr rec. 26 BF, CP dropped to 350*.
50% cond, gas vol. after swb 400 MCFPD; 30 min after, 240 MCFPD. Rec. 41 BC, 16 BFW.
Left opn to tank on 3/4" chk @ 6 PM.
5/20/86
Well flo'd 21 bbl in 13 hrs, tbg flo dead § 7 AM, CP 400*. Start FL w/swb 8500' &
scattered to SN, made 1 run/hr, rec. 17 bbl in 10 hrs. 24 hr rec. 38 BF, 7 BW, gas vol.
meas. directly after swb 400 MCFPD, 1 hr after swb pull 240 MCFPD. Left tbg opn to tank
on 3/4" chk @ 5 PM. SI. Drop from report until work begins.
5/21/86
51 8 AM, hook-up flo line to frac tank & pit. Opn @ 11 AM on 3/4" chk, 4 hr SITP 400?,
SICP 725*, left opn to tank. This AM: SICP 500?, FTP 0. Gas vol. @ 8 AM 140 MCFPD,
flo'd 36 BF in 21 hrs. PU Petroleum Tech WL & RIH w/tandem bombs, set @ 11,985' for
7 day build-up. Start tst 9:30 AM, May 21, 1986. No further report until May 29. 1986.
C-947
DRLRPT/D 1
-------
MUREXCO PETROLEUM, INC.
WEEKLY DRILLING REPORT
MAY 23-29. 1986
FRYE ll-29/COMPLETION
Wheeler Co., TX
Sweetwater Creek Prospect
Murexco/Operator
MPI WI:
1986-A
5/29/86
Pull bomb 9:30 AM, May 28, 1986. Petro Tech pulled bomb & ran static, 168 hr dead wt
SITP 3410#, SICP 3696#. BHT (11,985'), 210°F. Fluid sample results from 5/21/86:
Wtr
Grav. 1.057
pH 5.4
Chlorides 45,373
bicarbonates 254
Na 24,924
Ca 30,999
Mg 642
Fe 144
Oil
48.4 API corrected
Pour pt. 12°F
DRLRPT/D 1
C-948
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
MAY 9 - 15. 1986
FRYE fll-29/COMPLETION Murexco/Operator
Wheeler Co., TX MPI WI:
Sweetwater Prospect 1986-A
5/13/86
15 1/2 hr SICP 600#, opn csg to tanks on 1/2" chk, gas for 2 min, press down to 0# &
then solid fluid. Rec. 757 bbl in 24 hrs. 1709 BLTR.
5/14/86
p 7 AM, FCP 155 on 42/64" chk, rec. 12 bbl fluid, 10% cond.
-------
C
MUREXCO PETROLEUM. INC.
MEEKLY DRILLING REPORT
MAY 9-15. 1986
FRYE ll-29/COMPLETION Murexco/Operator
Wheeler Co., TX MPI VII:
Sweetwater Prospect 1986-A
5/9/86
1050# FCP on 12/64" chk. Open to 16/64" ck, 925# FCP @ 2:30 PM, open to 24/64" chk
e 4:30 AM 550# FCP, flo 28 BPH. Rec. 648 bbl in 21 hrs. 1570 BLTR. SI @ 4:30 AM '
This AM: SICP 950#. RU McCullough, run G-ring, set pkr.
5/10/86
SICP 950#. RU McCullough WL & run 4.437" OD G-ring & junk basket to 12,181'. Rec.
2,pieces rubber from junk basket. SIH w/5 1/2" BkrQtodel F B-l pkr, pkr Ht-dwn
& 12,050' from surf will not go up or dwn, pkr jumped up hole 1'. SICP 1100?,""flo
well on 16/64" chk after flo'g for 5 min, pkr jumped up hole, 50' to 12,000', pkr
will not go up or down, cont. flow no fluid to surf.^flo on 24/64" chk, press to 0.
No gas flow. Call BJ pump truck. RU BJ, load csg 26 bbl 10# brine & press to 1800#,
held solid, bleed off press & set tool. POH w/wireline, RD McCullough & BJ & SI.
SDFN.
5/11/86
SICP 90#, bleed off. RU Dotco rev. circ unit, press csg to 3100#, pump out plug, SD,
SICP 1200#. Dotco pmp'd 266 bbl 10# brin w/additives, pmp rate 3/4 bbl/min @ 1900#.
ISIP 1900#. Flo back 150 bbl, show of gas on last 50 bbl. Call BJ pmp truck to
attempt to kill well, wait 3 hrs for BJ. CP built up to 1250#. RU BJ kill truck 0
6:30 PM. Pmp 300 bbls 10# brine w/additives, 1st 150 bbls 5 1/2 bpm @ 2600)?, 2nd
150 bbls @ 5 1/2 bpm @ 2100#, ISIP 1900#. Open on 24/64" chk, press down to Of
in 20 min. Flo'g solid steam fluid, flo 75 bbl in 75 min. SI @ 9 PM.
5/12/86
10 hr SICP 750#, BJ pmp'd 300 bbl 10# brine w/additives, press inc. to 2100# &
stabilized, 5 1/2 bpm rate. SD. ISIP 19501, 15 min. 1650#, 1 hr. 1100#. Opn csg to
tank on 24/64" chk, flo back 45 bbl in 50 min. SI press inc. to 500# in 2 hrs. BJ
?c£nl 30?Tbbls 10-2# b)"ine w/additives, rate 5 1/2 bpm G> 2100*. ISIP 1950#, 15 min
J?rS ;«n!! for day @ 3:3° PM' Total PmP'd to attempt to kill well 896 bbl. This AM:
SICP 600#, flo'g to tank on 34/64"chk.
C-950
DRLRPT/D 2
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT"
MAY 2 - 8.~ni%F
FRYE 21-29/COMPLETION
Wheeler Co., TX
Sweetwater Creek Prospect
Murexco /Operator
MPI WI:
1986-A
5/6/86
25 psi FTP, 75% oil rec. 6 BF lite mist open to 1" chk. Made swb run, FL 10,000', run
swb to 11,500', no fluid rec., cups torn. RU BJ to kill well, pmp 65 bbl 2% KCL w/
additives via tbg, bleed off press, press csg to 35002 for 10 min - OK. Remove tree
unseat pkr, run 10 J tbg thru perf, TOH. POOH w/tbg & pkr. SDFN. This AM: prep to
frac.
5/7/86
SICP 125. RU BJ. frac w/117,200 gal RXL 5, base fluid 2% KCL w/.25/gal xcid 102,
1 gal claytrol 3, 1 gal inflo-40/1000 gal, ran 5% diesel thru 4 ppg sd, tot sd
237,0002 20-40 ottowa, flush w/11,130 gal 102 brine. During pad, press inc. from
31002 to 41002. @ start 1 ppg 41002 w/3 ppg on form, press dec. from 41302 to 32002
in 7 min, start flush. Complete job 12:30 PM. Tot sd used 217,0002. Avg. press
36 BPM @ 3800; ISTP 27002 w/102 brin, 5 min 23002, 10 min 21702, 15 min 20102. 2 PM SICP
19502. SI for gel to break. 2933 BLYTR. This AM: SICP 1450.
5/8/86
SICP 14502, open on 12/64" chk, @ 11:30 AM 11002 FCP, reduced chk to 8/64", @ 4:30 PM
13002 FCP, open to 12/64 chk, @ 5:30 PM 12002 FCP, @ 8:30 PM 13002 FCP; Opn to 16/64"
chk G 12:30 11002 FCP. Reduce to 12/64" chk. This AM: 10502 FCP on 12/64" chk. Open
to 16/64" chk @ 8:30 AM 10002 FCP. Total fluid recovered 754 bbls, 2179 BFTR.
C-951
DRLRPT/D 4
-------
MUREXCO PETROLEUM. INC.
wTEKLY DRILLING REPORT
MAY 2 - 8. 1986
FRYE ll-29/COMPLETION . Murexco /Operator
Wheeler Co., TX MPI HI:
Sweetwater Creek Prospect 1986-A
5/2/86
RU King Drlg. Pulling Unit, RU Welex to perf. Start FL 150' from surf. 2 7/8" tbq de'irt
livered from W.6. Baker, threads on talley, 403 J 2 7/8" 8.7# N-80 (12,597.5').
Correlate w/CCL & prep to perf w/4" hollow carrier, 120° phasing, hole size .56",
penetration 14.8". 1st run failed, 2nd run ffeTf3£$92-32Wi' 19_holes;
12,010^12,018 17 holes; 3rd run start FL 90' from surf, perf J£^70-73' 7 holes;
61,980-87' 15 holes; 4th run FL 90' from surf, perf lXS5J£56' 13 holes, fcU9£D"- ,,
41,966'- 13 holes, total perfs 84 holes. SIH w/tbg & pkr. Run 150 J. SDFN. This AM-i
TIH, 0 TP, 0 CP. "i
5/3/86
SITP 0, SICP 0. Cont TIH w/tbg, threads off talley 403 J 2 7/8" 8.7#
N-80, (12,512.98') tbg & tools in hole 1 E3^^fi^HM)aiTS8^SJJi:bpW^1ff (5.75')
1 2 3/8" standard SN w/change overs (2.25') 382 J 2 7/8" 8.7# N-80 (11,862.14'),
total 11,870.14'. Set pkr w/18,000# compression, install tree close BOP. Start
swb'g, FL surf after 4 hr., FL 8000', tot. rec. 41 BW.
5/4/86
SITP 0, SICP 0, lite gas blow. Start FL 7500'. FL 300' above SN 3' flare in
front of swb. Rec. 18 bb. RU BJ to Hettixp^i/SOOO gal 15% HCL + . 1 gal/1000
NE-6 & 1 gal/1000 Claytrol 3, run 6 bbl acid without balls, 126 7/8" ball sealers in
66 bbl acid, flush w/62 bbl 2% KCL, hole loaded @ 57 bbl form, taking fluid @ 2500 psi,
Pmp 5 bbl/min 9 3200#, ball out to 5000#, surge balls, cont. flush, SDFN. Avg. rate
4.8 BBl/min G> 3400#, ISTP 1650 psi, 5 min 1510 psi, 10 min 1470 psi, 15 min 1450#-psi,
BLTR. 1 hr. FTP 420, 32/64" chk, 70% oil, est.
gas 300 MCF. @3 hr. FTP 0 on 32/64" chk, good gas blow, flo'd 25 bbl, open to 1" chk,
bleed off. @4 hrs FL 8000', scattered 75% oil, strong blow behind swb. FL 9500' scat,
swb 10 bbl, no fluid on last run, tearing rubber off cups, cannot swb below 10,300'. R.
w/overshot to clean out rubber, started out @ 10,500', nothing recovered. RIH w/swb cu|
*0J0'3001 Pushed to 10,900', FL G> 9500', lite blow, no fluid rec. Cups torn, wait 11
5:30 PM, FL 9280'. Swb stacked out @ 10,900', no fluid rec. Rec. 25 BO, 11 BW. 107'
wtr rec. after acid, 25 BLTR. SDFN. This AM: SITP 925, SICP 300, open on 1" chk, flo/
oil, set chk @ 48/64".
C-9S2
DRLRPT/D 3
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT"
4/25/86 - 5/1/86
FRYE n/COMPLETION
iheeler Co., TX
Sweetwater Creek Prospect
Murexco/Operator
MPI WI:
1986-A
4/25/86
LDDP, set 5 1/2" csg. Circ, cmt. ND BOP, set slips.
Released 7 AM 4/25/86. Run 5 1/2" as follows:
Jet & clean pit, RD. Rig
1 Baker Float shoe; 2 ff^!72" 20# N-8 LT&C (84.42'), 1 Baker line float collar;
270 J 5 1/2" 20# N-80 LT&C; 29 J 20# S-95 LT&C; 1 J 5 1/2" 20# P 110 LT&C; total
length 12,513.31'. Thread locked FC, 1st J, shoe, ran 20 centrailizers. BJ
cmt'd job. 10 bbl gel wtr spacer, mix 550 sx Cl "H" cmt + 3% KCL + 10#/sx gilsonite,
+ l/4#/sx celo flake, + .8% FL 19 slurry @ 14.8#/gal, yield 1.39, volume 136 bbl
Displaced w/272 bbl 2% KCL w/1 gal/1000 gal NE-6.
5/1/86
Made final cut on 5 1/2" csg. Install B Section tst to 15001. Install 6" X 5000#
hydraulic BOP. RU Welex. Ran CBL/CCL/GR w/portable mast. Tagged fiBHU&KttlW
w/1000# press on well. Had good to excellent bonding from PBTD 0 12,331' to top of
cmt 9 10,550' across interval to be perforated 12,075-11,810, had 80% partial bonding.
C-953
DRLRPT/D 5
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
"""APRIL 18-24. 1986
FRYE n-29/DRILLING Murexco/Operator
Wheeler Co., TX MPI MI:
Sweetwater Creek Prospect 1986-A
4/18/86
Depth 11,195' (551), 29 days from spud. MW 9, V 47. Survey: 11,169' 1 1/8°.
This AM: drlg.
4/19/86
Depth 11,405' (2101), 30 days from spud. MW 9, V 38. This AM: drlg.
4/20/86
Depth 11,652' (2471) 31 days from spud. MW 9+, V 39. This AM: drlg.
4/21/86
Depth 11,915' (263') 32 days from spud. M 9, V 41. This AM: drlg.
4/22/86
Depth 12,270' (355'), 33 days from spud. MW 9, V 42. Survey: 11,169' 1 1/8°.
This AM: drlg.
4/23/86
Depth 12,500' (2301), 34 days from spud. MW 9.2, V 55. Survey: 11,169' 1 1/2°;
12,244' 1 1/2°; 12,496' 1 1/2°. RU Schlumberger, first log on bot 8 AM, 12,503',
DIL/BHC/GR/Calip.
4/24/86
Depth 12,500' TD, 35 days from spud. MW 9.2, V 51. 1st log DIL/SFL 12,478-3516';
Sonic 12,478-8500'; LDT/CNL/ML 12,478-8500'. This AM: LDDP!
DRLRPT/D 6 C-954
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
APRIL 11 - APRIL 17. 1986
FRYE ll-29/DRILLING Murexco/Operator
Wheeler Co., TX MPI WI:
Sweetwater Creek Prospect 1986-A
4/11/86
Depth 9400' (2141), fm sh. 22 days from spud. MW 9, V 35. Survey: 7453' 3/4°. This
AM: drlg.
4/12/86
Depth 9510' (HO1), 23 days from spud. MW 8.9, V35. Survey: 7453' 3/4°. This
AM: drlg.
4/13/86
Depth 9839' (329'), 24 days from spud. MW 9, V 36. This AM: drlg.
4/14/86
Depth 10,165' (326'), 25 days from spud. MW 9, V 34. This AM: drlg.
4/15/86
Depth 10,470' (3051), 26 days from spud. MW 9, V 36. Survey: 10,460' 1°. This AM:
drlg.
4/16/86
Depth 10,825' (355'), 27 days from spud. MW 9, V 36. Survey: 10,460' 1'
This AM: drlg.
4/17/86
bepth 11,140' (3151), 28 days from spud. MW 9, V 34. Survey: 10,460' 1<
This AM: drlg.
C-955
DRLRPT/D 5
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
""APRIL 4 - 10. 1986
FRYE #l-29/DRILLING Murexco/Operator
Wheeler Co., TX MPI WI:
Sweetwater Creek Prospect 1986-A
4/4/86
Depth 7550' (2801), 15 days from spud, fin. sh. MW 8.8, V 32. This AM: Drlg.
4/5/86
Depth 7935' (3891), 16 days from spud. Fm sh. MW 8.8, V 35. This AM: Drlg.
4/6/86
Depth $219' (2841), 17 days from spud. FM sh. MW 8.9, V 34. This AM: trip.
4/7/86
Depth 8450' (2311), 18 days from spud. MW 8.9, V34. This AM: drlg.
4/8/86
Depth 8745' (2951), 19 days from spud. MW 9.0, V 34. This AM: drlg.
4/9/86
Depth 9010' (2651), 20 days from spud. Fm sh, 1m & sd. MW 9, V 35. Survey:
7453' 3/4°. This AM: drlg.
4/10/86
Depth 9186' (1761), fm 95% sh, 21 days from spud. MW 9+, V 35. Survey: 7453' 3/4°.
This AM: TIH. y
DRLRPT/D 6 C-956
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT
MARCH 28 - APRIL 3. 1986
FRYE ll-29/DRILLING Murexco/Operfctor
fiheeler Co., TX MPI WI:
Sweetwater Creek Prospect 1986-A
3/29/86
Depth 5485' (4501), 9 days from spud. Fm. dolo. MW 8.7, V 30. This AM: drlg.
3/28/86
Depth 5038' (7001), 8 days from spud. Fm. dolo. MW 8.7, V 30. Survey: 3527' 1/4C
This AM: drlg.
3/30/86
Depth 5885' (400'), 10 days from spud. Fm. dolo. MW 8.6, V 42. This AM: drlg,
3/31/86
Depth 6270' (3851), 11 days from spud. Fm. dolo. MW 8.9, V 32. This AM: drlg,
4/1/86
Depth 6600' (3301), 12 days from spud. Fm. Sh. MW 8.8, V 32. Survey:
3513' 1/4°. This AM: drlg.
4/2/86
Depth 6900' (3001), 13 days from spud. MW 8.9, V33. Survey: 3513' 1/4°.
This AM: drlg.
4/3/86
Depth 7270' (3701), 14 days from spud. FM. sh. MW 8.8, V 32. This AM: drlg.
C-957
DRLRPT/D 5
-------
MUREXCO PETROLEUM. INC.
WEEKLY DRILLING REPORT"
MARCH 21 - 27. 1986"
FRYE n-29/DRILLING
Wheeler Co., TX
Sweetwater Creek Prospect
Murexco/Operator
MPI WI:
1986-A
3/21/86
FIRST REPORT: Depth 257' (2171), fm. redbed. RU, drld. to 257'. RU Csg
crew. Ran 7 jts 13 3/8", 54.5#, K-55 csg (262.68'), set @ 257'. RU & cmt
w/100 sx 85-15 "A" + 3% salt, l/4# seal-a-flak + 100 sx Class "H" w/3% cad.
Circ 15 bbls cmt. WOC. This AM: NU on 13 3/8" csg. Spud (? 5:45 PM. 3-20-86.
3/22/86
Depth 1475' (12181). NU 13 3/8" csg. Drl. plug & 59' cmt. Survey: 553' 1/4°;
1057' 1/4°. This AM: drlg.
3/23/86
Depth 2551' (10761). Fm. lime. Three days from spud. Survey: 1328' 1/2°;
2050' 0°. This AM: drlg.
3/24/86
Depth 3390' (8391). Fm. sh. Survey: 2521' 1/2°; 3000' 3/4°. This AM: drlg.
3/25/86
Depth 3527' (1371). FM sh. 5 days from spud. RU BJ. Ran: 1 shoe 1'; 25 jts
8 5/8" 32# K-55 LTC 1026.44'; 58 jts 8 5/8" 24# K-55 LTC 2410.82', 2 jts 8 5/8
32# K-55 LTC 80.65'; DV tool 3'; total 85 jts 3521.91'. Set 8 5/8" 8 3501.91'.
Ran centralizers on 1st, 3rd, 5th & 9th jts, 1 cent, above & below DV tool & 1 every
4th jt thereafter, (11 cent. ran). 4 gist bars on shoe, 6 on next 2 collars.
Survey 3513' 1/4°. This AM: cmt'g 8 5/8" @ 3501.91'.
3/26/86
Depth 3555' (28'), 6 days from spud. Fm. lime. Drld cmt. Checked BOP. WOC to
1 top. Crnt'd 294' of 1" of 100 sx Class "H" 1.96 yrd, 12.7 wt. Cut off & weld head,
NU & cut DL. Survey: 3527' 1/4°. This AM: drlg
3/27/86
Depth 4335' (7801). FM sh. 7 days from spud. Survey: 3527' 1/4°. This AM: drlg.
C-958
DRLRPT/D 3
-------
ATTACHMENT D: MUD REPORTS
C-959
-------
C-960
-------
;)323-9321 (214) 368-2490
C. W. KELLEY, JR., INC
Contulting Engineer
7818 IDLEWOOD LANE
DALLAS, TEXAS 75230
June 24, 1986
Mr. Jerry Mullican
Director
Underground Injection Control
Railroad Commission of Texas
P. 0. Drawer 12967
Austin, Texas 78711-2967
Dear Mr. Mullican:
RE: Murexco Petroleum
Frye #1-29
Enclosed please find the information you requested on the
above referenced well.
If you need any additional information, please let me know.
Sincerely .
C. W. Kell^f/Jr.
CWKjr/as
Enclosures
C-961
-------
BJ-TTTAN SERVICES COMPANY
FRAC/ACID LOO
FRAC 0* ACID DATA
Leottlon
inonA-nn*. <£±A*i,7t. &j£&*t "" ^
JOI TYPE: C>T^ ""-^ &&*<*'
WILL DATA: T«i< Dtpth.
Tubing: «'»
,W*igM.
.bplf
Mpm
Volum*.
Dvpth
PMker: Mik*
BrWakPlug: Make.
P«Herttlon: (it*.
fm* >/; forn Tn
»«m To
.8PF.
From.
.Total Shott.
Te_
To_
To_
£JL
SOBSIM
Oih« ni«.r..r
JOB PROCEOUR£
PpgSindw/.
.Blll4*W*of
.gall/Will of
ppgSindw/.
Sindw/.
PpgStndw/.
LOW RATE
**T
HPM MAXRATE
10MIN:.
.P8I
16MIN:.
I'd
C-962
3MO Nblll f a 20:01 98, 61 NHI
-------
JUN 20 '86 07:45
BJ-TITAN.SERWCES COMPANY
CO*
P.I
FRAC/ACID LOG
FRAC OR ACID DATA
Tlek*( No..
^WELL DATA; Total DB
Tublnj: BiK_2
Depth.
SUl_
Z3
. Factor.
VnlumB
.W«lgnt.
f.eto
Volume
£s
'limr fill*
F»«or
.bplf
HdjePluo; Mike.
f»rfor«tion $iie_
Stt tt
fiPP
.Tot»l Shoia f7
_To
iftan.
"*fOftt_
.To.
. Tc.
Pram
.To
,To
_5_
. geli of.
SOB Sire
. Type.
-Sp. Gr. /•/ Me /3-C*
Typ« ,
JOB PROCEDURE
.gali/btHsof.
. g»fi/bbi» of.
.gals/bWa of.
.gals/bblso(.
.gtli/bblt of.
. gili/bblt o<,
w/.
w/.
w/.
w/.
w/.
w/.
w/.
w/
.. PP8 Sand w/.
_ ppg Sand w/..
_ pp« Sand w/.
_ ppg S*nd w,11;
. ppg Sand w/,
. ppfl Sandw/.
. ppg Sand w/.
.ppg Sandw/.
-tcl/t>blN2
-sof/bbl NZ
. Bcf/bbl N2
^Bcf/uu! N'2
IN2
.sef/bblN2
.ad/bbl Na
.Hcf/bbl N2
VMMNV REPRESENTATIVE
PRESSURES PSI
TUBING
ANNULUS
FLUID PUMPED DATA
TOTAL
FLUID
Pump«d
Time Period
AATE
SWt/Min
REMARKS
IL
?
.• j
Zl/,
R.n.c-
MAX. PRESS.
Pfil
AVG. RATE
10MIN:
V • O
BPM LOW RATE
PSI 16 MIN:
3 '
MAX RATE
S'f
,PSI
,0PM
.PSI
-------
A nn\ HUGHES DRILLING FLUIDS
n^miKB j. ,0777N w F,,»w,v SlJ ,, 70'.
^"•""^^ |7I3| 68G-3823
.ITERATOR
m PORT FOI;
TT^
T|^V
111 ; DEPTH -
Jet' IDAH 19
M b^MLlUAfE PRtSEN[ ACTIVITY
^±J
CONTRACTOR KICJ NO '
HtPORMCin SECTION. IOWNSHi?Ui
wVElL NAMf AND NO | HELD OR BLOCK. NO Comily. Piiribh u Ollb luie died b 1 A 1 1- HHUVINCE
r " ' . r .' . •
DRILLING" ASSEMBLY ; CASING j MUD VOLUME (BBLl | CIRCULATION DATA
•til Si/E "ivpt jFTSi/[ , vnrAi' ,MOlE PI!'. M||vp .1 X IN ANN'iLAR Vtt if! Ml
: " SIZI .2 ' x IN DP DC
OR,, P,P[ T, Ft LENulH ,r,7' Rr. G
Funnel Viscosity Isec qtl API u °F
Plastic Viscositv cP n °f
. .,>iu Pom' HI !'.•'.' tt'l
Gel Strerq" • 'ii •C""'H:t 1 0 sec lOmtn
1 ,11'Stf API ic'"1 30 mm '
Ai ' HTHP Filtiutt IC.TI' 30 mm ) „ °F
Lake Tl-.icki.e.., ,32nd ,n API/HTHP)
S' ''^ Content r , by Vol ) calculated re un
Liii.nO Ccntfi! ' . by Vol i Oil'Waiei
S.i'iO Content i' by Vol )
Methylene Blue Capacity Ib bbl equiv c ..'^ ,'• i
RECOMMENDED TOUR TREATMENT "
'•' j i
— . r - i,
1 ' '
' •- *•' /.- '
.---'• , :
• , , . •', ''" A ''?
"'! ' ' '-, Y/' •: '• ' '
' *"" t
'';' •'''•' • A f; ,'-' '>/•' ^/f - -^
REMARKS - GIVf OPFHAIION DH-IH AND NAU.Rt 01 AN' fholLEVS 1 \rpiJNtlR10
', f: ' ' ' ; • -
,,, .,--. . -,
f**:"f*-~ '
*J..(. . ' '
( ;
s '
1 ; • -
*-»
////// EQUIPMENT
/ / / / / / DESANDER H'l'DCL
f i ' | DESILltK DtGASS
j " HI SP SHAKER CENTHIF
1 DAILY COST
fz-T T '
'NVLNTORf ! ! II'' ICUMULATIvt COt'
ORDERED 1 i ~ ' f -' -f -f • -*--• — - — -) j
' '0"Y 1 ; \ i
: NCjiNELIi I. i-/L • •• '. "
^j — j. . ^. " '. i ' ; •
£,.^"t '--•!.'.;:;. 'tC'-''':; '.'.;•.''.• ' .••-•-•!
••'••. • i;H -V
•.'•••:; H> r i'
..i ,,..( ... <.•
M -bi, L i n 'MF 1 w -L ' "I '•:
.: ,, •-•,! .,, r. • , .'i I ,-. . •-.- ,••., r.f':^\.L- ' W ™'
':•• ..L.I' -.1 -t. . . -. V :, ./^EHM^ spi:;HO
2^964
-------
faoHm*} HUGHES DRILLING FLUIDS
JFMTtTi'trtf Houston. Te»S3 772?7
«•*•*•'•'• (7131680-3823
OPERATOR
R| PORT (OR
A'tLL NAME AND NO
ffp\\
I ) t^
1. / jbl'IID
19 •
DEPTH
UATl . PRESENT ACTIVITY
CONTRACTC'R "^1
RE FUR T FOFi
.- *
i lEi-D OR BLOCK No Cu irt
DRILLING ASSEMBLY CASING MUD VOLUME (BBL)
j I bliE TYPi.
(
>• .L P:r! rYt L
OR'LL f'f". T> PE
L.ftlL. COLLAR SIZE
lE'S^E S,RfACE HOLE P.I3 p,,Mp
LENGTH ','tPfv'll AM TOTAL CIRCULATING Vi'LUMF ! f'i iVP
'/ ' '
LtNGI'1 iNTlp.^lLD:AU IN STORAGE i^'EIGHT BBL S
LENGTH ' I,' iQHC Hi 'N OR LINER N'.ID BBL W
TYPE /,
I
MUD PROPERTIES
U.Ml-lerrom
;,.,,. ^mpltld^n
^...iir-fTeTrerjiurs-F
Deptfi ct'
v. I-"-' ippg)
1 ullliel Vl>-C'lv1y ISCL 0
III) cu It S|. 0
•• API ,
"F
1' -IM'C Viscns-ty ~r *' °F
i.i'.itPi.ml lib 100 tt'l
..i ..»i'"i|th ill 100 ft1) 10 sec 10 inn
i IP. .I*- API ICMI- 30 m
API HTH.F Filtrate (cm'
C
-------
( 1 HUGHES DRILLING FLUIDS
1 MUOHE» 1 ,07^7 N w Frfeoay. Suite 7CO
•SfflWirTB 00 Boi 22753
jj 'Jill ?.'(-» Houston Te.BS 77227
•^' (7131 680-38.^3
OPERATOR
REPORT FOR
WELL NAME AND NO (
FT , , v .' - :
DRILLING 'ASSEMBLY CASING
en SI.TE
i '
PHIL: P'PF
•JH'LL PIPE
DH LL COLLAR
/-•'
TYPE JET SIZE Sl.'Rt
1 „
TYPE LENGTH INTERr/C
TYPt LENGTH IN1ERVII
-CL
D'ATE
UIAIE
SIZE LENGTH PRODLICI.ON OR LINER
- " — .'". ' "
/If - DEPTTH •
Jrl-/ DATE .'19 / •
M. , SPODDATL PRESENT ACTIVlfY "~ —
I _ ,._ .. ' I ' / ,'
CON1HACIOH < RIG NO ~
1 ' ' t' -'
Rf.PORT FOF1 6EC1ION iowSShiTS
"v'r »- '• /M' ., ,'?V
HELU UH BLOCK Nu • County. Paribli dtUllbhore area SI AH PROVINCE
-' ' ' ' ^ /' '- . i
MUD VOLUME (BBL) CIRCULATION DATA ""
HOLE PITS r.n.r •' * IN ANNLILA1 VFl iFll
F*v Ifyll' L ' r
Sl/f -2 . • X " IN DP '- -' 'DC /;
TOTAL CIRCULAT'NG VOLl ME PUVI" fVAKF M3DEL TARSI IMED CIRCUl ATIQN ""
^— ' ' ;:. .' •' ' EFf-, PRESSURE |PSi| ,-....
IN STORAGE WLIGHT B8LSTH SIIOMIN BOI10MS
UP (MINI
MUD . BBL'MIN GAL, MIN TOTAI CIRC
TYPE/ ' ' j ' ' / ' ' :~'S TIME|MIN| / > .-
T . , A , ', _ . _. - , / V f<
MUD PROPERTIES
Sample From
:.,,., ^n,,,,e I..K,,,
f -jwt'M*- T en-.[i
e'dture 6F
Oei'lh |i|
Weigl"
^F.-ti', Mb cu It Si.G
fu<-<'iel Visrob.ty ibec qti API „ °F
°,,3M,CV.SCOS,.ycP „ °F
Y if 'd Pumt Mb
'j* Slicngth I
1 .I'r.ilo AF'I u-
1 00 It'
rj 100 lt;l 10 sec 10 mm
,•30 mm,
F L
PIT
- /* , . '
-~
,
/
/' /
'•
AF' HTHP filtrate li.ni1 30 mm „ °F | —
Cane ThitknebS 132nd in APIHTHPl
Solids Content (' . by Vol ] calculated retort
vnuia Cimter-
Sdnd Content
N'er*-y -ne 5iue
['H St
Alkalinity Mud
:•" by Vol ) Oil Water
'••t by Vol )
Capacity. Ib bbl eguiv cm^cm-1 mud
rip ' Meter '/ °F
r~
AlKai.nity Filtrate |P|/M)|
Ai'erndle Alkal
nity Filtrate (P1/P2I
CMoride |mg LI
Tcta1 Hardr.esb as Calcium (mg'L)
PRODUCT
'NVENTORY
STARTING
INVENTORY
7- •'/
-? "*T~
^/L1l*
^~" —
^
* >'
/'"•»
/'^ /./-•
. /
/.'V. " '.
-,y
v —
* ' 1
xS^^K^xS^
^A^"]^'/^' 7< //' , ,x
RECEIVED
3ED LAS! _ ' ^ -
.-.•-INU
Nvf N'tlRY
•M't°t:'
-^-U-
' - '
jn^_^_/' -
. ! i
• ', ', A-VL. OR Ri '_ •:•: , : \~. ,-
F L
PIT
y/ i
/
/
/
/
I--/
/
/ X
i
; , -.-: ? ,
/
MUD PROPERTY SPECIFICATIONS
WEIGHT; ' • - . VISCOSITY— . FILTRATE
//..-• / „// -..^ /.. r
RECOMMENDED TOUR TREATMENT
'"'.• .' - /•'.>>• .
. j- r •.-.- <"- - x- -.
^ . , - ; • ;
//•V/-. />,-, .;'/, .... /, C"- vv,,.
REMARKS - GiV '^t'ERAriON DfP'h AND r
-------
HUGHES DRILLING FLUIDS
107'7 N « >i.«w«, Suili- 7M
(7131 680-3823
H'fRAIOR
DATE
19
DEPTH
SPUD DATE
PRESENT vACTlVITt-
' '
CONTRACTOR
FEl'OH' »
REPORT fOR
SECTION. TOWNSHIP. RANGE
WtLl MAMt AND NO
r"
HELD OP. BLOCK NO
County Par sh or Onshore area
STATE -PROVINCE
DRl-ING''ASoEM3LY
CASING
MUD VOLUME (BBLJ
CIRCULATION DATA
' SUE
JtT S ."t"
Sl.Rr ACt
pipr
,NT[ Rvr:.' ATE
HOLE
-2
IN
IN
TOTAL CIRCl LATI>,rG VOLI'VF PUMP MAKF TfrCDE L
ASSUMED
EFJ.
'•
STK.-MIN
ANNULAR
IFT M'Nl
CIRCULATION
PRESSURE (PS'
DR LI
LENGTH
IMERMEDIATE
!N STORAGE
BBL'STK
BOTTOMS
UPiVN,
,11,.L COLLAR SIZE
LENGTH
•REDUCTION OR LINER
MUD
TYP^
BBL'MlN
..' / ,"
GAL MINI
/ '''?/•
~' '
TOTAL CIRC
TIME (MINI
MUD PROPERTIES
e From
T.m>- Sdmplt
Ft jwi.ne Temper.iture °F
Depth (in
MUD PROPERTY SPECIFICATIONS
viscoswr
.'S-
FILTRATE
RECOMMENDED TOUR TREATMENT
vVe-y'il iPPy)
.H Vis
cP ,
Pom' |l|j 100 lt:!
•ji-i Slrentjlh ML 100ft:i 1 0 sec 10 nun
• API [cm- 30 c
A*1 H'HP Filira e (cm 30 mm » ,i
C«>t Ttuclnesi l32nd .n API'HTHP]
1 CcmtpMt r by Vc'i ) Cdlculoted fut-nt
/~
7 7 /'i /• ^
I H- 0 Cunlnni I-: by Vc1 I O'l Waler
Sand Content '' by Vol )
enc Blue CdpJC'ty Ib bbl equiv en*1 cm1 mud
REMARKS - G'VE OPERATION DEPTH ANO NAT<. Re OF ANY PflOEKFVS ENCOUNTERED
/ J
Str p
Meter
; Alkalmily Mud [Pm|
, F.nrbte iF
-------
r^
r> H
1C
1*9 p
UGHES DRILLING FLUIDS
777 N w Fieewav Suile 70C
3 Boi 22753
uston Te»as 77227
3l 680-3823
uPtRAlOR
REPORT FOP
«V[ LL MAMl AND NO
DRILLING' ASSEMBLY
B n SIZE
TRILL Pli'E
S'ZW-:
URiLL PIPE
DHiLL COLLAR
r
TYPE.
TYPE
1YPE
SjZE, •"
JET Sli'E
^ENGTH
LENGTH
LENGTH
CASING
SURFACL
INTERMEDIATE
<.//'
INTERMEDIATE
n
PRODUCTION
tl
OR LINER
Jrl-'l DATE - 19 •
_J^ j SPiOFiAH . KHtbfNT AtliylT t "^
l.uNIRAi.1 ;H ' RlC NO i •
REPOR' FOli SECTION TOWNSHIP iJ
l It LD OR BlUCV NO • Ci.unty. Pa-ish ou'ltsnore area tHAif 'PROVINCE "
<:>,'••-, ;' " - •- •.-'•
'MLJD VOLUME (BBL) CIRCULATION DATA
HOLE PITS ,||JMF .1 X IN ANNL'LARVEL (FI V
•"•"••''/" -' '- -: SlZ[ -2 / X/~" IN DP •' ' M ,',
- • - / • - _ . ^ i '.
TOTAL CIPtCULATTNG VOLL ME PI IMP.MAKE TWODEL ASSUMED CIRCULATION /"
," ' , • i .•'-' '•" *J+^ ' PRESSURE |PSI| .. /,„
v'( t ~~ '•'•'•' ' '/•'•' 0,0 /VV'-.
IN STORAGE WEIGHT BBL.STK -STiWMIN BOTTOMS ' '
UP IMIN|
. •• -•_/ .- /,. !/„•_'/ •••/ -
MUD BBL MIN ' GAL WIN TOTAL CIRC '
TYPE/ /, /'//•' ' -•'••*"> TIME (MINI / ;'/
/-''' /''l •' • : / '' *? /•-' f'' .'
MUD PROPERTIES
L smple Frorr,
. n.t f,.-.i,|,.e 70.C"
r ,.;,„ 1 ,.„.,.,.,. ,.,,re°F
in ,,t
,'. - g'it
.Piipi
PMSIIC VlSCGSlU CP l<
• HiJ Point (Ib
Oi-. Sl'e'igih i
( •!:'.. IP API (err
100 n;i
1- API .,
°F
b cu ft
b 100 tt;i 10 iec 10 mi
-' 30 m
AP! HTHf-1 Filtrate (cnij
^oM! ThiiJkiie:,
build;. CoMent
I Hi id Ciintfil
::.tiu! Omtenr
r/finvlc'ie Skip
I-H St
AI..,:.III|> Mud
A • (|. nity Flltra
Ai-...n,eAlKa
i32nd
n )
30 mm
) •'
F
n
°F
SpG
n AP1.HTHP]
I'-.- by Vol )
calculated re
nrt
1- by Vol } Oil Water
' . by Vo
1 )
Cjpdcity Ib bbl eiiuiv
'p
Pm,
Meter <:
cm1 r.rr
°F
l Mlllll
te IP) M(i
nity Filt
ate (PI
P2I
Ciii.mde irr.g Ll
T *.!.(' Harcres-
as Calc
um (mq
LI
'•^^
•NVFNTORY
RlCl VI D
SF'.' : iT
;-4 HO
i "'. r,, ,
NVE -ill.)-.'
RDtRir.
i vr'A>
/^~~'$-
i'*
/-'
f ''
|/r'i'?
' , ,
y7
/v
/
t ( '
,'
,, V^
//
1
F L
i-WT
'/ .'--TA
- —
, ;' •.
'">
(•'.. /
^ /'
/J
•'J-/^
/~ ]
jr
c:
/
••. /
,'
S
--/
' / '/ '•••'
•s '' y
i
r L
PIT
• i
/
/
/
/
/
/
/
*///
>L. -<-- i-ll.. ._ . .
^ ' ! ; ' /
., ..
MUD PROPERTY SPECIFICATIONS
WEIGHT— i _ ^ VISCOSITY ./ -- / FILTRATE
/ '- •• f •& •>'/. ; ,.'•'
RECOMMENDED TOUR TREATMENT
f
'.' • f ' * 'i '
: ->- -*• -.- <,• > f', .
.- " '* " ' ' * ' , .'
•*'/-•' t
f\'. .: . *. s< , n ",< - / • /\ // i V.
REMARKS - c-vf - ^f HAtiCiA. n[prw AND NAruRf OF *fjy PROBLEMS ENCOUNIEPED
? / ./ / x ' ,A ' ''.- -y* •'•
r- / ^/' "
^ < /
. J , ; '_"' / ' ' ; j ^- : //
/ / / / / / EQUIPMENI __
/ / / / / / DESANDER MUDCl
' — -t— - *- . DESILTER DEGAS.
t ' HI-SP SHAKER CENTRI
~
1 1 DAILY COST
^ i ;£,,,/ ^'-'
; | 1 I CUrVTULATlVE COST
/''//' "*H_—
3^968' ' ••••-•'••-••-•iVO"/FLFlf' -5'1"
-------
[HUOHBI
Wr^fi^^^
w^jM^^^^
r\ H
U 10
*' |7I
UGHES DRILLING FLUIDS
77 N Vi Freeway Sjile 700
jsU-i In.iij 7722;
31 680-3823
OPERATOR
REPOB1 'OR
WELL NAV1E AND_I<0
\ ; /". "*"
*\J DATE _l'-; .' '^ 19 -fj.
DEPTH -> — -j—,
1 b^UD OAH - , PRESENT ACTIVITY
V ' ^ - ' / t /-' • '< •• -
CONTRACTOR
REPORT FOR
FIELD OR BLOCK NO Ctjunly. Pansn or Offshore area
' .--:/ ;'• ^ ', ;•' , " • ' '
RIG
NO
SECTION. TOWNSHIP, RANGE
STATE PROVINCE
DRILLING ASSEMBLY CASING MUD VOLUME (BBL1 - ' CIRCULATION
n Sl?l
DRILL PIPE
SIZE
DRILL PIPE
blZE
DRILL COLLAR
TVPE
TYPE
TYPE
SIZE
JET SIZl SuR'ACL HOuE PITS ., x IN
t H i i r*fl i ,
S'« 42 - X /-',N
LENGTH NTERMLD.ATt TL TAL CIRCULATING VOLUME PUMP MAKE MCJDEL [ ASSUMED
„ - / EfK,
1 " - '. /I =..
LENGTH INHHMEDIATE IN STORAGE WEIGHT |BBLSTK STKMIN
LENGTH PRODUCTION OR LINER MUD ^ BBl'M'lN GAL MIN
MUD PROPERTIES
Sdmpl*- From
Tune Sdinplfc T
dken
Flowlme Temperature °F
Depth (III
Weight
ippgl
Mb cu ft S(> G
Tunnel Viscosity (SeC'Qt) API <
Plditic Viscosity cP ii
V it-Id Puml lib
100 ii'i
CM Suengll' Hli 100 t
°F
°F
•'l 10 SCL 1 0 mm
ti'lrdle API (cm1 30 mm I
API nTHP Filtrate lcm>
Cake Thickness t32nd
Solids Content
'30 mm
i » °F
r, API.HTHP)
l°t by Vol 1
Liquid Conlent I' . by Vol i Oil
Sana Content
calculated retort
Water
«- by Vol )
Methylene Blue Capacity Ib.'bbl equiv. . cirv-cm-1 mud
!>H Si
rip
Metei ,r °F
Alkalinity Mud (Pm)
Alkalinity Filtrate |P| M||
Alternate Alka
nity Filtrate |P1
P2)
Chlnride (mg LI
llilil Haroness.
as Calcium (rriQ L)
F-RODJCT
\VIN10RV
Nvf MORY
HiUlVED
- —
''SfD LAST
It MR
'•W^y
i «DEP.?,_
/^
1''' I
,J(,
•^IL-u.-* T"..
,: •.-:
••:'*•.?
F L PIT
''"'•'' /
/„. ;-;
' 1 "~ '- . .
//
'
/
/
/
/
( L PIT
/
/
/
/
/
"W/y-/-////
f "/
i '
1
':\" '
M" ' ''
V —
-/'•• 1 ''
DP
DATA
ANNULAR VEL |FT MINI
DC
CIRCULATION
PRESSURE i.PSh
BOTTOMS
UP IMINi
TOTAL CIRC
TIME (MIN)
MUD PROPERTY SPECIFICATIONS
' ' • . /• /^ i .-
RECOMMENDED TOUR Tl
/-. /X
-jXi * "
r- / // ,-r ^
.'.' . / • • '.T -^<
' . ' ' _,
••>"":• -*- r .-.'- (',-,-r't y/i"'- •
— .'' ' " >/' ••, /.•
V • - . T ( * . A1 S - / / f
~ . , i i
.- /> >'.'?' :
REMARKS - GIVE OPERM;OU DEPTH AND NATURE OF ANY PROBLEMS PTJCC^MERED
/ ft.:-. J Sf. XV..- ' ••-"
-'•••• .'• r / < • /l
' ' •• • -
J'.;.': i: / :/"5
r •
' '• '• ' ' . , >•
r it, , i. n r^ '__
,.
; , /
i ,/?< '^ -.
i/--^-— •' —
////// EQUIPMENT
/ / / / / / D
. . U
' H
DAILY
^_p i
ESANDER MUD CLEANER
ESILTER DEGASSER
SP SHAKER CENTRIFUGE
COST
CUMULST'VE COST
i • .' .
i
i t
HO'.U t'H IN: jlVO6.ll I'M I1,' _, ''
_^L_. J.;- .. •'
' ' 1 .- .
- '-> _i_—
WHSE PHONE
~P£
. a? '•_-;: ' :• • . SL =
-------
f HUOHB
OPERATOR
T^i HUGHES DRILLING FLUIDS
• 10777 N W Freeway St.'le 700
fm PO Box 22753
^' 1710)680-3823
J\J DATE .'--JZ 19.-"/
DEPTH •
-, /•;>,'
M. bHUDDATt .. . KHbbtNT ACTIVITY ' ' /-
h^ ^J r •-.>.-/ f •
^ - - -,7. .' L. I ,f u
V-
REPORT FOR
CONTRACTjOP.
REPORT FDR
"WELTNAME AND NO , FIELD OR BLOCK NO ' • County Pa-uh or Ollshore area
r— -f-: / - -? '? 7 ;-1" < , f
filCi NU ,
OCLIIUN. TOWNSHIP HA
•*C9
STATE/PROVINCE ~
DRILtlNd ASSEMBLY ' CASING "TV1UD VOLUME (BBL) CIRCULATION DATA ™
B:T M.'E
DRILL PIPE
SIZE / : ___
DRILL PIPE "
SIZE
DRILL COUAR
TYPE ( JET SI.-E StlRFACE HOLE ^ PITS - P,,M|. " X IN
TYPE ^ENGTH ISTERMCDIATE TOTAL ClRCULATWti VOLUME PUMP MAKE. MODEL ASSUMED
"', ,/ - ' '--^"/" -''; •• <*,
TYPE LENGTH NTERMtDIATE IN STORAGE WEIGHT BBL.STK 51KMIN
jIZE LENGTH PRODUCTION OR LINER MUD -- _ gBLIvTlN GAt/^IIN
"•' ' MUD PROPERTIES
Sample From
Tune Sample Tdnen
F In-line Temperature °F
Depth Itti
Weight
Ippgl (Ib/cutt) SpG
Funnel Viscobity Isec qtl API ,. °F
Plastic Viscosity cP (i °F
Y icld Point lit
1 00 tt'
Gel Strength lib' 100 lt!| 10 sec 10 mm
din., la API (en-
1 30 nun )
API HTHF Filtrate (cm1 30 mm ) ,; °F
Cake Thickness ,:, -1 n. API ITHPi f
Solids Content (% by Vol.) u calculated reu'rt
Liquid Content
Sand Content 1
Methylene Blue
PH St
("(. by Vol ) Oil/Water
°-. by Vol )
Capacity 1 . Ib7bbl equiv - cm3/cm-! mud
ip f Meter « °F
Alkalinity Mud (Pm)
Alkalinity Filtrate iPf'Mfi
Alternate Alkalinity Filtrate |P1 'P2|
Chloride Img'L)
Tetal Hardness as Calcium (mg/L)
i
PRODUCT
INVENTORY
STARTING
•NVENTORY
RECEIVED
I'SED LAST
?4 HR
L! OS'Nb
INVENTORY
ORDERED
I i ) I> A Y
f NG'Mt R
NCT'CE ,-
sc ;.ECT
.'AS L T.
FL .
' ' ^-
* ~ J ~*
', ' /
f
""
,',/r
/• c
/ •
'. /
'•4^
x^V >
/ • y* ^^
/A C;
^.
O/ / 7.
--/""'
•«.: / /»/-.
C/,v-/-'l
F L PIT
/
/
', /
/
/
/%7^^////
£i$-MzJ£.
' 1 ' '
Ci / y
- 1 , / ' •
Hl)M[ PHliNf
ANNUlARVEl IFT M
DP / r. DC -^
j ,
CIRCULATION v.
PRESSURE IPSII /^•<, ,
BOTTOMS ' ' i
UP (MINI ,-, ;
TOTAL CIRC
TIME |MIN| St'll
t .1 y **"
MUD PROPERTY SPECIFICATIONS
WEIGH^. / f-, VlSCOSffX.
FILTRA/E „
RECOMMENDED TOUR TREATMENT
A
x -; " // L '
* * ; • A j.'V'-,
-' -*'• • / .'"' :v ^-'~
.^ yVx. V' • '''c >•'/•:
.'}•> / • • .'.'.' . •/./. ^ /^
/// // /tO / 's?,,-* &M ',f~ &„ ?.i( /'/; .
REMARKS - GIVE OPfRAIKfa DEPTH AND NATURE OF ANY PHOBLEMS ENCOUNTERED
±(i>; •>/ »'!t /: /i)t ••/•» fa>
III' \ 0 -/ • - -
^J -J ; /'v ,
,-"' /'r///L
>t. u //./ /;/ Ij/
J
*E**-TT
X/ / / / EQUIPMENI
/////™
^ L)t
n HI
DAILY
4|| /
; /
MUD ir F'n, ir.i v
•' '•' *" ', / ''
SANDER "MUD CLEAN
SILTER . DEGASSEfl
•SP SHAKER ' CENTRIFUG
COST
L^STIVE COST
™*?™.--j&
N, OPIN o>, A -jo OR ?ic;.'/M;-;f/." -. i vrfti;c:fD ORili_y J!( ^:. - -•. ., .. • . • ....... ,,, ..ARft. CAS1 ., LV/.ND VIVBEUSE'DIFTHE JSi;
^SuMED^^Vi^^/^^-^^V^^^r-r'"^"^ ' ;'' ' "•--OP.RCCT-NF5SORCOMPLETENESSANON.
C-970 .
-------
HUGHES DRILLING FLUIDS
1G777 N V* freeway Suile 7CJC
?O Bo. 227S.3
Houston Teias77227
(713i 680-3823
DRILLING MUD REPORT NO.
DATE
19 •
SPUD DATE
DEPTH
PRtSpKT ACTIVITY
AERATOR
TCONTRACT.OR
REPORT fOR
RIG NG
S[PUfiT i'JK
SECTION. TOWNSHIP. RANGE
(VEIL NAME, AND NU
r
FIELD OR BLUC* NO
County-Pji ih u> OHbhore area
STATE PROVINCE
DRILLING ASSEMBLY
fU ' .'E
Jt F Si.'
CASING
SL'RI ACL
MUD VOLUME (BBL)
CIRCULATIO DATA
I'OLC
irViiER'/FDiAiE
PITS
IN
ANNL'LAR VEL (FT MIN)
DP ,V --- DC ; ^ -
LL PIPf
S'ZF J 1 '
OTAL CIRCl LATINu VOLUME
PUMP MAKE. MODEL
ASSJMED
CIRCL'LATiON
PRESSURE IPS1;
DfUL PIPE
LENGTH
NTERMEDIATE
IN STOFiAGE WEIGHT
BBL/STK
STK MIN
BOTTOMS
UP (MINI
E-TJ3L
DRILL COLLAR SIZE
LENGTH
PRODUCT ION OH I INER
MUD /•
TYPE/''
t ' •
GAL MIN
TOTAL CIRC
TIME (MINI
MUD PROPERTIES
Sdmple From
nme Sample Token
flowlme Temperature °F
Depth (In
MUD PROPERTY SPECIFICATIONS
WEIGHT,-^
*' . S-*
. .
'
VISCOSjTt7
'
FILTRATE
RECOMMEtMDED TOUR TREATMENT
Weight
ippg;
(Ib, cu ft )
Si- G
-i-Jt.
funnel viscosit> (sec qt) API
Plastic Viscosity cP «
Yield Point lib 1 00 It-)
Gei Strength i IU 100 If 1 0 bee 10 inn
X
F.ll'ate API (cm1 30 mm I
API HTHP Filtrate (cm> 30 mm i i
Coke Thickness :32nd in API HTHP)
Solids Contenl ((t by Vol ) calculated retort
-4-^
l«|uid Content l"i by Voi 1 Oil Water
S.ind Content I", by Vol
Methylene Blue Capacity Ib bbl eqmv cm'en
Strip
Meter
°F
Alkalinity Mud IPmf
Alkalinity Filtrate (Pi Mfi
Allemate AlVb.mity Filtrote |P1 P2|
Chlori' » (mg L)
Total Hardness as Calcium (mg L)
REMARKS - GIVE OPERATION DEPTH AND NATURE OF ANY PHOBLE vs ENCOUNTERED
" ' '• •''•' ,^s^: v^ fa
,./,. , ;,,;;;
EQUIPMENT
DESANDER MUD CLEANER
, , DESILTER OEGASSER
HI SP SHAKER CENTRIFUGE
DAILY COST
CUMULATIVE COST
WHSE PHONE
i.'C"., r-i~J\M .'. H '.' PL'TE '.- •.•/•
-? . IV iS ASSUME C tOR ANY C«'-'•'•
. i\p f.'AVBE uSl r> ^ 'HFI'SER
i-S OR COV-'.FTtNEES AND?40
-------
IHUOHC
OPERATOR
FEPOR*FOR
T^ HUGHES DRILLING FLUIDS
1 10777 N W Freeway. Suile 700
*"S PO Bon 22753
^' <713I 680-3823
;V| --1 r
/If : , 1 DEPTH" •
f\J DATE - 19 -1'-.'
M SPUD DATE PHESEN) ACTIVITY ' ~
CONTRACUJR HIG NO,. '
REPORT FOR SECTION, TOWNSHIP"^
WELL NAME AND NO " FIELD OR BLOCK NO County, fjnili or Ullsllort aced bl Al t, PROVINCE
\ "i* !, * ' ' /'>*'','. f/ •/• •> •' >- ~f~]r~ '•'"'
DRILLING ASSEMBLY ' CASING MUD VOLUME (B^L) CIRCULATION DATA """
Bil SIZE ,
"1 A/
DRILL PIPE
•3'2E / ' '
/• ;* *
DR'LL PIPE '
SIZE
DRILL COLLAR
T-iFE JET SIZE SURFACE HOLE PliS / puMp *1 X _.1N
T :;v '< Y> " ^ ,}V/" ^-.'>r- SIZE ,2 xr x/^.-IN DP
ANNULAR VEL IFT.W
/' ' '-S~ DC js -
TYPE' ILETJGTH .(NTERMTDIAVE TOTAL-CIRCULATING VOLUME PUMP MAKE. MODEL ASSUMED CIRCULAIION "'"
1 „ / >"r < J. ,' ' '• E/T> '• PRESSURE |PSI| ,(,
TYPE LENGTH INTERMEDIATE IN STORAGE WEIGHT BBL.'STK • STK/MiN BUI10MS ' '
.,, . . - f: / UPIMINI i
SIZE LENGTH PRODUCTION OR LINE R MUD f BBL'MirY GAL'MIN I01ALCIRC ' l'
I .. i . . „ TYPE /.-' jf • r . ^ — . / TIME (MINI pjy •>
1 '- MUD PROPERTIES
Sdmple From
1 rint Sdmple f
aken
flowl-ne Temperature °F
Depth (ft.
Weight ',,
r unnel Viscub
.(•PPQ) 'b cu tt ) Sp G
V iiM Qti API „ "F
Plasuc Viscosity cP « °F
Yield Point (lb
100 (I1
Gel Strength i Itj, 1 00 M: / 10 sec- 10 mm
f tlUdte API (err
] 30 mm |
API HTHP Filtrate (cm^'30 mm « °F
Cake Thickness t32nd m. API HTHP} ! "
Solids Content |0io by Vol.) calculated retort
Liquid Content
Sdnd Content
MetnyleneBlue
rH St
!"< by Vol ) Oil Walet
'. by Vul |
Capacity, lb bbl eqtjiv cm3,'cm3 m.ij
PRODUCT
INVENTORY
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-------
faaHm*} H7^^EFS DRILLING FLUIDS
EtjtffffPBP Houston Texas 77227
*"*~™—^' (713)680-3623
OPERATOR
REPORT FOR
vVELLNAME AND.NO
7r " ••
• *
J\J DATE ..-^ --V* '19
A SPUD DATE J ,
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CONTRACTOR
REPCR1 Ft)R
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DRILllNi ASSEMBLY ' CASING MUD VOLUME (BBL/ CIRCULATION DATA
BIT SIZE TYPE
DRILL PIPE TYPE
DRILL PIPE TYPE
SIZE
DRILL COLLAR SIZE
1 .l*'*^
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LENGTH INTERMEDIATE IN STOR/cl WEIGHT BBL,STK Si
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LENGTH PRODUCTION OR LINER MUD BBL WIN GAL/'MIN TOTAL CIRC ^
£~ 1 } / , fc TYPE/''? j,j ^Q "*">/ TIMEIMIN| L-S * -J-
MUD PROPERTIES/
Sample From
Time Sample Taken
Flowlme Temperature °F
Depth (III
Weight . Xpogl
. (Ib/cu tt ) Sp G
Funnel Viscosity (sec/qtl API .< °F
Plastic Viscosty cP
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PRODUCT /t",
INVENTORY / V
STARTING , _ ,
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USED LAST ^
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WEIGHT- » ,-r^ ,-y VISCOSJJY
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FILTRAT^
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f >i HUGHES DRILLING FLUIDS
1 HUOHa» | ,0777 N yv Fr»ew«> Suite 700
^*™~*^' (713) 6SO-3823
OPERATOR
KMftV-V
REPORT FOR '
.rl-' DATE.--'- ^f/- 19 '
1 SPUD DATE . PR
^ •' -" .A . ,V/
CONTRA£TpR ' -
REPORT FOll
— 'Or.!,' '] N'.'^'T /:' '' y. '..
WELL NAME' AND NO -< FIELD OR BLOCK NO > County, r ansh or OMshore dred
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DRILLING ASSEMBLY CASING MUD VOLUME (BBL.J ' UKUULAT ION DATA
B'T SIZE TYPE JE! SIZE SURfACE HOLE PITS PUMf" ^. X /
; V(i rC, '- , ^ /'""-'-• v <:?^/ •-••'' b"E ^ ~: x/
"RILL PIPE """"ITYPE LENGTH INTERMEDIATE TOTAL CIRCULATING" VOLUME PUMP WAKE MODEL ASSUM
SIZE i i « ! — 7 ~ - - ' E/'^7 -
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SIZE ,,; . ^~ j
DRILL COLLAR SZE LENGTH PRODi. CTION OR LINER MUD ..
1 -Z- y "~ / / ii TYPE,'' .' /
MUD PROPERTIES
Sdmple From
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F lowline 1 empprature °F
Depth lit)
Weight ^-Ifpg) (Ibcutt) SP G
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-------
r-~"^ HUGHES DRILLING FLUIDS
1 MUWW»j 10777 N w Freeway Suile 70C
JMIfffTit^li Houston Texas 77227
'*""*~^' (7131680-3823
UPERATC : t
RtPORTFOR '
WELL NAME AND_NP
v/
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pRILLING* ASSEMBLY
/'/;; -A-J.
DRILL PIPE TYPE
DRILL PIPE TYPE
SIZE
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-— ^. DRILLING MUD REPORT NO.
Ill - • DEPTH / r;
±IS DATE , . - . 19 /• ( i-^-> /
M. SPUD DATE PRESENT, ACTIVITY
\—J - ,' -r/ L, ->
^^ , *. i. • ^' / .;
CONTRACJOH ' RIG NO '
h f. . _3 *•'
REPORT FOR SECTION, TOWNSHIP RANGE
HELD OR BLOCV NO ' Couh y, Par-ish or Onshore area STATE/PROVItvCE
CASING MUD VOLUME (BBLy ' ' CIRCULATION DATA
JET SIZE SURFACE HOLE Pi'S PUMP -1 X tN- ANNULAR VEL (FT.'MINl
_ -, V"A'>;;'/ ?^*-r ^,-.--S,ZE .2 :r"x//,NO"/x^- - ?^>;
LENGTH 'INTERMEDIATE TOTAL CIRCULATING VOLUME PUMP MAKE. MODEL ASSUMED CIRCULATION
^ , —j— .' '-.•'' Er^-j . PRESSURE (PSl) , j
LENGTH INTERMEDIATE IN STOFfAGE WEIGHT BBL/STT STK/MIN BOTTOMS f " ,
,,; .. <~• — /', ;rj TYPE/ f ir, , f~y r-> — - •» / TIME (MINI f_j . TL'
MUD PROPERTIES
SiTiple From
Time Sample Taken
f lowline Temperature °F
Depth |tt|
Weight ippgl
(lb,cult| SpG
Funnel Viscosity |sec qt) API (/
Plaslic Vu .osity cP «
•F
°F
Yield Point (Ib 100 It'
Gel Strength (Ib 1 00 It2 1 0 sec 10 mm
Filtrate API (cm1 30 m
API HTHP filtrate |cm>
Cake Thickness [32nd
n)
30 rr.m //
n API HTHPi
°r
Solids Content (»,. by Vol.) calculated rei.-ri
Liquid Content IV by Vol.) Oi 'Water
Sand Content (°T by Vol )
Methylene Blue Capacity Ib/bbl equiv cm3, cm' rnutj
rH ' Su,p
Me er .ic
°F
Alkalinity Mud (Pm)
Alkal.mty Filtrate |P|/M|I
Alternate Alka inity Fill
,lte (PI P2|
Chloride (mg'L!
Tola! Hardness as Calcium [mg'L)
y. c !•
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'NVENTOflY / N
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INVENTORY III*.
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y^ y' y' / / / •_ DESANDER : MUD CLEANER
| i.. ULblLIkH DEGASSER
THI-SP SHAKER "CENTRIFUGE
DAILY COST
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-------
r— — ~\ HUGHES DRILLING FLUIDS
By Suilt 7(10
27
^•AJL*^- 7131 680-3823
OPERATOR
lV;!r
REPORT FOR
f-" •"
WELL NAME AND NO
v; -
. / . _
J-ly JDATE • .'
A SHOO DATE
LJ^^-/
CONTRACTOfi
I Ti
REPORT FOR
f IELD OR BIOCVNO ' County Pan:
; . -V .' '.. ; * ' . I i :•'
DRILLING' ASSEMBLY | CASING MUD VOLUME (BBL/
B'T SiZE TYPE
DRILL PiPE, T>PE
DRIl- HIPF. TYPE
SiZE
DRILL COLLAR t _i
/FIT
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'; / • ' '
LENCTH PRODUCTION OR LINER MUD BBL'MIN
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MUD PROPERTIES '
Sample From
T ime Sample Taken
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Depth (It)
Weight (ppg) lib cu tt | SpG
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n
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Cake Thickness (32nd in API'HTHPl
Solids Content C*c by Vol.)
calculated ' retort
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Sand Content I'.c by Vol I
Methylene Slue Capacity Ib, bbl equi
PH . Strip ". . Meter ,t
j crn-' 'cni^ mud
°F
Alkalinity Mud (Pml
Alkalinity nitrate |P|/M|]
Alternate Alka imty Filtrate (PI
•P2)
Chloride (mg'Ll
Total Hardness as Calcium (mg'L)
' f •' •
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MODEL ASSUMED LIHCULATiON L
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; - - DAILY COST
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-------
e HUGHES DRILLING FLUIDS
10777 N W Fr»«*»y Su.lc 70C
Houston Texas 77'-.' :v~; r--.xr. ,
FIELD OR S^OCK NO ' ' County. Parish or Oflshore area STATE TROV:NCE
.''• .' . •' • '• J/' .'* -i IT'S?
ORILLING'ASSEMBLY CASING MUD VOLUME IBBLJ CIRCULATION DATA
BTSI/E TYPE
/ u ~- '"
DRILL PIPE 1YPE
™S 1 ',
DRILL PIPE TYPE
SIZE
DRILL COLLAR SIZE
I LS
Sample From
JET SIZE ; SLIM ACE HOLE PUS pi . i x IN ANMVLAB VEL IFT MIN,
\ -••'•"...,- ' -"-// ^/'•r SIZE ,2 - x // IN DP / /-.. DC .^.-T -
LENGTH 'NTEBMTOlATE TOTAL CIRCULATING VOLUME PUMP fv'AKE . MODEL ASSUMED CIRCULATION
„ r7 "> ") / TIME (MINI f. ^ '. _t
' MUD PROPERTIES
F L
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Flfiwl-ne Ternperdture °F
Depth (111
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Funnel V.sco ly (sec nil API ,i °F
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Yielu Point |lb 1 00 lt:
GelSlrei din I Ib 100«-| 10 sec- 10 rr n
filtrate API (cnv, 3^ "• 1
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Cdke Thickness (32nd in. API'HTHP)
Sa'ids Content | Oil-
calculated i. retort
Water
Sand Content ("H by Vo )
Methyiene Blue Capacity Ib.'bbl equiv . cm! cm3 mud
PH Strip Meter .( °F
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Alternate Alkalinity Filtrate (PI /P2|
Chloride (mg'L)
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RECOMMENDED TOUR TREATMENT
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////// EQUIPMENT
/ / / / / / " DESANDER MUD CLEANER
••"• r ' - -1 HI-SP SHAKER CENTRIFUGE
DAILY COST
(^ I, Q//f ^
: . i CUMULATIVE COST
i 1 ! i i
' ; ' ' 7^' 1 ~~T_{'~ '
i
VllCL i\> i.f N L-N -••N.. '.-••••- •-•••••. i'
-'•''-CiI'S HOrtf kt R N «c:-l:l • '•
I !*BL ' •> 1C AS S ' V! I f '..M AN i 1 A '. -
;VDELI r_..N:. ^ ' WHSE PflONE
1 . »1 . - 1 - ~> .
/ '.- - ' . / ' ' V'/ ^ "• - •-
l " . . r'f- '
• .',..•:•.-';. CAR! - ..' ASU Vi ' Bf L SI 0 <~! ^F . SE =
:-; C-977
-------
S HUGHES DRILLING FLUIDS
10777 N ft Freeway Suile 700
(7131 680-3823
OPERATOR
V':'^
t . .
HEPORT FOR
WELL NAMt AND NO
©
DATE
''/-•
SPUDJ?ATE' .,
-, 19 ,
- -./ PB
CONTRACTOR .
i. ,r
REPOR FO^ '
FIELD OR BLOCK NO
DRILLING ASSEMBLY • CASING MUD VOLUME (BBL)
B'i SIZE
DR'LL PlPt
DRILL PIPE
SIZE
DRILL COLLAR
TYPE
TYPE
TYPE
SIZE
JET SIZI 'jtlRFACt HOLE P S
LENGTH INTER.VUD'Af E TOTAL CIRCULATING VOLUM
LENGIH INlEHMtDlAIE IN STORAGE WEIGHT
it
LENGTH PRODUCTION OR LINER MUD
MUD PROPERTIES
Sample From
T mie Sample T aken
Flowlme Temperature °F
Depth (HI
Weight
(ppg) . (Ib cu ft Sp G
fjnnel Viscosity (sec/qll API a
°F
Plastic Viscosity cP // °F
Yield Point (Ib
100 tt'l
Gel Strength (Ib. 100 ftj| 10 sec 10 mm
Filtrate API (err
API HTHP Filtr
3 30 mm )
te (cm"30 mm
) n. °F
Cake Thickness 132nd in API/HTHP)
Solids Content (°. by Vol 1 .
calculated i retort
Liouid Content (^ by Vol ) Oil/Water
Sand Content ("t by Vol I
Methylene Blue Capacity .. Ib/bbl equiv . cm3'cmj mud
PH Strip ' ' Ve
er ,,t °F
Alkalinity Mud (Pm)
Alkalinity Filtrate (Pf'Mf)
Alterr te Alkal
nity Filtrate (PI
P2)
Chloride (mg/LI
'LI .
PRODUCT
INVENTORY
STARTING
INVENTORY
RECEIVED
USED LAST
24 Hfl
CLOSING
INVENTORY
ORDERED
TODAY
ENGINEER
/&
ttl \*~
/(;/'
\C. /
— /
/
';*•'• \t<
4 ' l\.t
' County. Parish or Offshore are
M 'f ' - *
, DEPT^T-TTT-
'' •« - -?
ESEWT-.ACTiyiTY "~
ii i i. /.—
j^/ A^.
( HIG NU ,j
btUIUN. IUWNSHIP.RANO
l SIAJ_b|r_PHOVINCE :
1 £~ !• ( '
CIRCULATION DATA "~*
PUMP "'
SIZE ,2
jf
X
E PUMP MAKE. MODEL ASSUM
-' ^
_• / '
BBL STK
BBL'MirM
STK'N
GAL'W
IN ANNULAR VEL (FT MINf
IN DP /V« DC ^.••
ED CIRCULATION ~
PRESSURE [PSIl j , f ,
IN BO 1 IOMS ' '
UP (MIN) /, ' •• /
/ "^
IN TOTAL CIRC.
TIME (MIN) / . _^
MUD PROPERTY SPECIFICATIONS
WEIGHT _ r
1
_,'*,
V
ISCOSLT_i( -. -^ ,t FILTRATE i
^'.T-w'1 V ^" A" i -
RECOMMENDED TOUfl
A /' -:
/
TREATMENT
T('/'/ (l
/w:
.— '/ "t <,', ,^,,v ^_-,_ ^ "-••' (ffil[
"^
• r
f." 1
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REMARKS -G
/
^^/&//////,
' -.'<- -/;
/'
-^l" •-/
'
/ ' " .-'.' ' . / / '' '
^P
MOBILE PHONE
" U'l
t
vf OPERATION DEPTH AND NATURE OF ANY PROBLEMS ENCOUNTERED
/ • *' ' ' • t /^ ' i 3 '" •• • i ' , f i i > " "^
'
d
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/
c0Il,<"/,-^L?P!'c'7'N*fl'P r'H R"-L~' '•''•'''•'• •'•' '• i" -LS .i L> <•--, 1 v o:l v\ Pin; N HERL'N HASBEF.N PRE
'*", P T HU"EVER fi". REf-PL'j! •/ ,' ' . . i •:.,-..•:.. .M v i'. V-: i ••>(,, "St L \, "= O« r'LH iG[N!S AS '
..'•»!.'..• l_ A..S'.'M[D FCR ANY [,/•.'.-/. • • >" •. . . 'u V ' nr • ... n J/jWIg .7 g
'/
+ '
/
/ ^
•-• DA
CU
1 rr —
EQUIPMENT _
DESANDER " MUDCLEANI
OESILTER - OEGASSER
HI-SP SHAKER - CENTRIFUGE
LY COST
MULATIVE COST
WHSE* PHON^ __ j.tfi
f ARE D CARE FULLY AND MAY BE USED IFTHE.,^!!
J ITS CORRECTNESS OR COMPLETENESS. *NU»"
-------
r^ot**} HUGHES DRILLING FLUIDS
Uwffi^nH Houston Texas 77227
«*""**^" (7131680-3823
OPERATOR
REPORT FOR
WELL NAME AND NO _
" \
f\S DATE J ' ' 19- /'
A SPUDJJATE • PRE
*•«— '
— • — ••> . > - i
CONTRACTOR
•V".- • i
REPORT FOR
,. k- f V>.~ T >;.-',•]
FIELD OR BLOCK NO County Parish or Offshore area
, - r KT' ' ,» - /* .'"• .-'•, , ;' '•/; -••
NO.
DEPTH-
, / ; . ,.
SENT-ACTIVITY
RIG NO y
SECTION. TOWNSHIP. RANGE
*- '\ /
STATE/PROVINCE
DRILLING ASSEMBLY CASING MUD VOLUME (BEJL) CIRCULATION DATA
BIT SIZE TYPE
T/> 3:.
. t..
DRILL PIPE' TYPE
SIZE
DRILL PIPE TYPE
SIZE
DRILL COLLAR SIZE
JET SIZE SURFACE HOLE PITS PUMP " ' X '
"-' C: '/ "I' r/ Ijifi - 'V.V' ' SI2E .2 •<" x /'', ,
LENGTH INTERMEDIATE TOTAL CIRCULATING VOLUME PUMP MAKE MODEL ASSUME
Jl O '•/*•"' *• "^ ' ' Er**""",
X..VJ .' /T~ <" '• /< >
LENGTH INTERMEDIATE IN STORAGE WEIGHT BBLVSTK STK/M
sj /'_' ' •
LENGTH PRODUCTION OR LINER MUD • BBL/MIN GAL.'M
ft: TYPE// ^rv ; r-j r .. _ ,
MUD PROPERTIES '
Sample From
Time Sample Taken
Flowlme Temperature
F
Depth) III
Weight /Jflpg.'
(Ib. cu fl.| Sp G
Funnel Viscos ty Isec'qtl API „ °F
Plastic Viscosity cP n
°F
Vieid Pomt |lb' 100 tt1)
Gel Strength |lb. 100 ft-) 1 0 sec 10 mm
Filtrate API (cm'/30 mm I
API HTHP Filtrate Icm1
Cdke Thickness (32nd
/30 mm ) il °F
n. API.HTHPI
Solids Content |% by Vol.) 1 calculated retort
Liquid Content (% by Vol 1 Oil'Water
Sand Content 1% by Vol )
Methylene Blue Capacity L.. Ib/bbl equiv v cm1' cm3 mud
PH ". Strip
CJ Meter e °f
Alkalinity Mud (Pml
Alkalinity Filtrate (Pf/Mf|
Alternate Alka mity Filtrate (P1/P2)
Chloride Img'L)
lolal Hardness as Calc
um (mg L)
PRODUCT X-
INVENTORY /\^,
STARTING
INVENTORY 3i /'
RECEIVED
USED : AST ,<• **.
-*"* Ai
'CLOSING ,
'NVENTORY '"V
ORDERED '
IUDAY
INGINFER
-^i~r~~T
1 F L PIT
it'1 A /•**
—
J **' ' V
r t
^ ' ,
£-
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y.>•(;.
HOMf PHl,;;l
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NOTICE AN1 OPINION A'
so ELECTS HOWEVER N
HAB.L.T', IS ASSUMED F
go OR Rf COMVC '. JA;
G REPRESENT A' v C
OR ANY DAI/AGS s (T
•J ANNULAR VEL (FT/MINI
D CIRCULATION
PRESSURE (PSII > J , „
^ A' /"' ,
N BOTTOMS ' .
up(MiN) ^ •' ' ;r
N TOTAL CIRC '
TIME IMIN) /^. ^- £
MUt) PROPERTY SPECIFICATIONS
WEIGHTJ"/ ^ VlSCOSOf ^. -5
y FIL"AJ^X, - '
C RECOMMENDED TOURTREATMENf
^ZjC A'Mr
*/ ..• fl- -j- /iMr/
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/ i/f 'ff.i,'- /T7/
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Hrt<( ' -r'1/ ,(,» it)f
REMARKS - GIVf OPERATION. DEPTH AND NATURE C
£ ' / • '•• -r >
fcl ( >l 7 /V- .''/•> T' ' '
_.. /'
/' /.' ' ' . / ., ,-
. • • .* /P-.^;.
t; v •'/•--• / ' ' ^'
/ / / / / /
//•//// :
J' ' ••" - ^
DAF
^l3
CUt
MOBILE PHONE ,_
'/ / ' '
F ANY PROBLEMS ENCOUNTERED
' , -/- f '-
- J/:-., ffi/ j£ :
// /
-r/ ' ,- -K
EQUIPMENT
DESANDER MUD CLEANER
DESILTER _ DEGASSER
HI-SP SHAKER '"CENTRIFUGE
LY COST
7-y/!<
^ULATIVE COST
3/:>3f ^
WHSE PHONE
^ v ; ^y'r
._ '. t""'-. ~! Pi. - i.l YOR'ARIHENHERE'N HAS BE t N f RE PARED CAREFULLY AND MAY BE USED 'c T HE «.'SER
'• .'.•••'• ••-•.' • . V •; F BV u i^SEVViSJ-iR CL'R AGTr.'S AS TO US CORRECTNESS OR COMPLFTENESb AND NO
-------
f \ LJ
1 HUOHBB ^
jjljiifl^jj H0
OPERATOR
REPORT FOR
""^ |7
UCHES DRILLING FLUIDS
777 N W Freeway Suile 700
3 Bo> 22753
uston Te»as 77227
31 680-3823
iTSi
J:\J DATE - / *f 19^ /,
DEPTH~~T- —
'.* •'., "*
A bPIJUj^AIL :, t PHEbtM^-ACTiyiTV' " L~:
_ -.. -..)//' ./-••./ ./>:
y\^ -,
— — i—
WELL NAME AND NO
CONTRACTOR
REPORT FOfl ~
HIG NO r»
SECTION TOWNSHIP. R/
"' f_'V
S?ATE 'PROVINCE ~
DRILLING ASSEMBLY CASING MUD VOLUME (BBf) ' UHCULATION DATA
BIT SIZE .
""} -/1
l ' t
DRIfL PIPE
SIZE
DRILL PIPE
SIZE
TYPE
"v"-
TVH
TYPE
DRILL COLLAR StZE
JET SIZE StIRFACE HOLE Jllb puup .1 X IN
LENGTH ' ll--.
^^/f ; .' '/ •'* / /- V ^
*-* ^ MUD PROPERTIES
Sample From
Time Sample Taken
Flowlme Temperature °
F
Depth lit)
Weight
(ppgi
(Ib cu It Sp G
Funnel ViscOb ty (sec qt] API « °E
Plastic Viscosity cP "
Yield Point (Ib
100 It1)
°F
Gel Strength ilo 100 tt'l 10 sec 10 mm
Filtrate API lcmj 30 m
AP. HTHP Filtrate (cm'
(32nd
n )
30 mm ,/ °f
n. APi.HTHP)
Solids Content re by Vol.) calculated retort
Liquid Content |"i by Vol ) Oil'Water "
Sand Content (<\ by Vol )
Methylene Blue Capacity Ib'bbl equiv cm' cm1 mud
PH Strip
. Meter M °F
Alkalinity Mud IPm)
Alkalinity filtrate (Pf/Mf)
Alternate Alka
nily Fill
ale (PI P2I
Chloride Img L]
Tetal Hardness as Calc-um tmg/L)
PRODUCT
INVENTORY
STARTING
INVENTORY
RECEIVED
L/SEO LAST
24 HR
CLOSING
INVENTOR''
ORDERED
tNG HE! P.
^^ \
NOTICE L
SO E.EJ-
L'AB'L'T i
X
i -, -
(«((
» /
1 /
\. __ • ',
VO-
F L
--PIT
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--
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r'
"\ ~^
-f
~ /*
-4-
'-
vX/Y
' ^ -=> ^.
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j
^XXXX^
XXX-X-X
I _ 1 1
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'
/ :' • " - ';
- - j- - -
-=•'.(""
l'.Pi L ' ,'R ANN •-• •:. " •
f L PIT
/
/
/
/
'///
r '
i
ANNULAR VEL IFTIK
DP/^""' DC ^
CIRCLM.ATION ' /
PRESSURE (PSI) / „ ,
BOTTOMS i.
UP (MINI /,
// l^J "J*
TOTAL CIRC
TIME (WIN) .'/•,, ^
MUD PROPERTY SPECIFICATIONS
WEIGHT- _ • — • VISCOSWY.
>' Lf ' -/ % J> ^ &
*"?- . • — ' .7 -
RECOMMENDED TOUR TP
flit /., -" /r r./.-- •
FILTRATE
* 'f • • ,
EATMENT
•G f j>? "1<'l
(j^-^L _/ f-, ntfi., /./,, (h
i*)nr;:. -fa ?,?>?~ /-.•/
REMARKS - GIVE OPERAT ON DEPTH AND NATURE OF ANY PROBLEMS ENCOUNUHEO
//'•. •' . .'/ >'-. f '' . '•• ' '.' i £
i i ',
////>// EQUIPMtNl
//////-
r D£
" rl HI
DAILY
('- | [3 /"
SANDER MUOCLEANI
SILTER DEGASSER
SP SHAKER CENTRIFUGE
COST
CUMULATIVE COST
/" -V __
MOFJ'LE PHONE f."
'/' ' • ' '. ~~~f, >*
V/ISE PHONE
VV/-' '• lL-
•i. i- •'-...] IIH ,•.>-, :' NMTRE r, -,.v^3rEN "REl'ARECCAREFULLY ANDMAYBtUbtSIFJ^'^
-------
HUGHES DRILLING FLUIDS
10777 N W Fretwiy Suitu 700
P 0 Bo.22753
Houston Texas 77227
(713)660-3823
OPERATOR
DRILLING MUD REPORT NO.
DATE
19 n-
SPU
CONTRACTOR.
°EPTH
PRESENT/^TIVIIV
,a
REPORT F^IR
SfTTlON. TOWNSHIP. RANGE
'*?
. A
13 DESANDER ~ MUD CLEANER
Q DESILTEH J, DEGASSER
DHI-SP SHAKER '"CENTRIFUGE
NOTICE ANY OPINION AND OfiRfL '•''•"• '•'• •'
SOELiCTS HOWtVtR NO Rf F'HI '.: M A I .• i
LIABILITY IS ASSUMED FOR A.NY DA'.'.'-Cf ' Hi
:'H[ °StD ORALLY OR WRITTEN HrRfiNHflSBEtNTPfrARED CAREFULLY ANOM AY BE USED i-" THE L It R
'•"MY IS MADE BY OL''-SFLVf E 'JR (.'L'R AGt M b AS !!.' :I S CORRECTNESS OR COMPLETEM b^ AfJO NO
^ FROM THE USE OF S*MEgp 1
-------
HUGHES DRILLING FLUIDS
10'" N W Fuewav Suilo 700
PO Bm 2??i3
HouWon. Tniaa 7< ?27
.7 ? 680-JS23
I
DRILLING MUD REPORT NO.
DATE 'y - / 19'
DEPTH
PL1Q DATE
EpKACTlvrfy
OPERATOR
CONTRACTOR
RIG Na
REPORT FOR
REPORT FOR
EUIUN, IOWNSHIP RA[
'
WELL NAME AND NO.
V
FIELD OR BLOCK"rtG
County, Parish or Offshore area
I
!'.\t- ^'J
>T ATE/PROVINCE ~
DRILLING ASSEMBLY
CASING
MUD VOLUME (BBL)
CIRCULATION DATA
BIT SIZE
JET SIZE.
SURFACE
HOLE
PUMP
SIZE
• 1
«2
IN.
IN.
ANNULAR VEL IFT'M!
DP /^/^ DC ^
DRILL PIPE
LENGTH
INTERMEDIATE
VOLUME
PUMP MAKE, MODEL
IMPMAKE, ^
7/:•'•"',
' -\ -v , ,.
IN STORAGE" TWEIGHT
UMED
CIRCULATION
PRESSURE (PSI|
DRILL PIPT
SIZE
TYPE
LENGTH
INTERMEDIATE
BBL/STK
STK/MIN
BOTTOMS
UP (MINI
DRILL COLLAR SIZE
LENGTH
PRODUCTION OR LINER
MUD
TYPE
/
BBL/MIN
GAL/MIN
V9
TOTAL CIRC
TIME {MINI
MUD PROPERTIES
MUD PROPERTY SPECIFICATIONS
Sample From
Time Sample Taken
Flowlme Terrperature °F
Depth (ftl
F L >f IT F L. " PIT
n i •, • —\
t y •
FILTRATE
RECOMMENDED TOUR TREATMENT
We.ght
(Ib. cu.ft ]
SpG
Funnel Viscosity Isec'qt) API
Plastic Viscosity cP ii
fl't
Yield Point (Ib 100 MJ)
Gel Strength (lb/100 ft') 10 sec''10 n.m
Filtrate API |cmj.30 mm I
API HTHP Filtrate (cm"30 mm I ,
Cake Thickness I32nd m. API. HTHPi
Solids Ci.ntent l% by Vol.) _ calculated retort
L'quid Content |"o b': Vol ] Oil/Water
REMARKS - GIVE OPERATION, DEPTH AND NATURE OF ANY PROBLEMS ENCOUNTERED
Sand Content (°v by Vol I
Methylene Blue Capacity _ Ib/bbl equiv . cm3 'cms mud
." Strip
',"- Meter ,
Alkalinity Mud |Pm)
Alkalinity Filtrate (Pf'Mf)
Alternate Alkalinity Filtrate (PI/P2I
Chloride (mg/L)
Tctal Hardness as Calcium (mg-'L)
>/..r.(;
- ' if—"
-DESANOER :-MUD CLEW;
Q DESILTER L DECASSEH ,
DHI^P SHAKER "CENTRIfUGl
^TlCEA^Y OPINION AK:C 0°-tC'. •.••.•-•;: .-.',ON EXPRESSEOORALLYORWRITTENHERE'N HAS BEEN PREPARED CAREFULLY AND MAY BE USED iFTHFUSEJ
b-_E.LE5 S-HO_^'ENER NOR^BibLV .: ,'•. , .F, WARRANT Y IS MADE BV O(jlWfl«2oR OUR AGENTS AS TO ITS CORRECTNESS OR COMPLETENESS. ANDNU
IS ASSUMED FOR ANi L'*.-.V-•_ ; '. ";,r
ARRANTY :S MADE BV O
LTiNG FROr/ THE USt Or SAME
-------
IHUOHCI
IBTTHWTT
B^^^^^^t
OPERATOR
Rfpijfll FOR
PI HUGHES DRILLING FLUIDS
*| 1Q777 N W Freeway, Su'le 700
91 PO Bo* 22753
™ 17131680-3823
1
\ •
i •'':.•.
S~—-* DRILLING MUD REPORT NO.
/flM
/I ) • DEPTH ;--
•*• 1 DATE ' ' ' 19 '
A / SPUD^ATE , , PRES-E«JT ACTIVITY
^^^"^^^ ••-. / . t—
CONTRACTOR RIG NO
RFPOHT FOFt SECTION TOWMSHlP RANGE
-"'•• -. .,,•.,, , - , , r^'Cf'
WELL NAME AND NO FIELD OR BLOCK NO County. Parish or Offshore area STATE/PROVINCE
DRILLINd ASSEMBLY CASING MUD VOLUME (BBL) ' CIRCULATION DATA
Bii SIZE
DRlL . r PE'
SIZE! 1
i I
DRILL PIPE
SIZE
TYPL JET £,1/1 SuHIACf HOLE PiT^, . i x IN ANNULAR vE,. (FT MIN)
r ' ; M P
"TI'' , . " ' ' •*> f '•- -. *- ' SIZL .2 ~\ Y. i f IN DP •' • DC -•'' V '
TYPE LENGTH INTERMEDIATE TOTAL CIRCULATING VOLUf/E PUMP MAKE . MODEL ASSUMED CIRCULATION
._ , ,/ O t- f • ' - E^R PRESSURE IPSII / . , ^
A T /^, *> ' -^ •<, '-/ "A, / - , ^. /
T ', - LENLTH INTERMEDIATE IN STORAGE WEIGHT BBL/STk SIK.'MIN BOTTOMS
•n UP (MINI ..- ..- „'
DRILL COLLAR, SIZE LENGTH PRODUCTION OR LINER MUD BBL MIN GAL, MIN TOTAL CIRC
1 'x JY'r'^ " TYPE '' -" r'7 ' —.'- TIME (MINI ,, /
MUD PROPERTIES
Sdmple From
Time Sample T^en
Flowline Temp
erature °F
Depth (111
Weight
Funnel Viscosi
Ippgl (ib cu It ) Sp G
y (sec'qtl API a °f
Plastic Viscosity cP it °f
Yield Point lib
100 ft')
Gei Strength (ID 100ft2) 10 sec, 10 nun
Filtrate API (cm1. 30 mm )
API HTHP Filtrate (cm"30 mm ,i °F
Cake Thickness 132nd in API/HTHP)
Solids Content
CtebyVol.) calculated . retort
Liqu.d Content |°c by Vol ) Oil Water
Sand Content
'•< by Vol 1
Melhylene Blue Capacity Ib bbl equi". cm1 cm' mud
PH ' St
ip Meter IL °F
Alkalin ty Mud (Pml
Alkalinity Filtrate |P| M|l
Alternate Alka
mity Filtrate |P1'P2)
Chloride |mg L)
Total HatdneSi as. Calcium (mg L)
' > ( ' '
t
PRODUCT
INVENTORY
STARTING
INVENTORY
RECEIVED
USED LAST
24 HR
CLOSING
INVENTORY
ORDERED
F L ^-TT
/f'i'r: A'
i *
'/r "-
V '
"'l'.' '
" . f
F L PIT
f '
x
x
y-~ /
/
/
/^^^y(////
'!z }/
qy -r'^,
' ;
* \ • ' / ' ' *•"" " • ,' "~
MOT'CI .
so cue-
UABlLIT*
MUD PROPERTY SPECIFICATIONS
WEIGH* ^- ^^ VISCOSlly -,, __ _ FILTRATE,
' 'RECOMMENDED TOUR TREATMENT
(\, ' /-,- ".< •*<*'/>.',:•:
r f i- . .'' » v v jiy i ** J .' • ,' ' -T '"> . . v
1 <• X ' ^ v^« ^fe, ^B /
} ' -• ' ' X* ff ^T
/A M < / f" ^ / ^' , X - i^rf' / '*"^~
REMARKS - GV^ op*fl(*uon, DEPTH 4to NATURE OF ANY PROBLEMS ENCOUNTERED
/ '/•/,*, / . /^ ^ /J /"V/. /7/5-^/Xv/ t
/ t/ ^
' ~^ •, - - -- J 1 t I / \ ]
/ x~''-'*-''-^.
, /, ., /:.-,. i x..v r--*^
',,,/-- , ' ' p /. ;/.
.• , ' 1 '/ . /•*.•' /> 1
///'/// EQUIPMENT
/ / / / / / "_ DESANDER MUD CLEANER
. - HI SP SHAKER CENTRIFUGE
,
- J DAILY COST
/ r j . . <
CUMULATIVE COST
/ — i 7>/,' _
MOB.U.KUN, ^ ^ ^ .^ ^ ^^^ ^
• ". ' jf '..'_ N ANi: ' '• ' i '• ' "•' '. i • • !,i . [i 'HAU> O" WRITll N '(i iii '. "•'•' Hi ' '. i «t "UrtiCARMI'iLYANDVAVBIH?!! ' U'T TE»
b HC'V. E .! R '.° c! I'H! '-: • ' ''• .'.•'<• ..',.< . VAOE B1 u C'--*l9'8;3 '' ' ' " -'-'i :'•'*•"•' ' ' ' -- C'JRPEC' NF SS ('P O 'M'^LE T t Nt L j i1. r SC
• S ASSJVLO ""'H AN1- L .'••.•.- . ' '.'. cr: V '^f USE 11' ci'.'S
-------
HUGHES DRILLING FLUIDS
10777 N VY Frecwa> Su.le 7rV
PO Bo. ??'L1
(7131 680-3ST3
ill-FRiTOR
f
DATE
SF'IJDAIE
19
DEPTH
PRESENT ACTIVIT/
CONTRACTOR
RF F'ORl FOR
A'rLi NAM1 AM. Ml
~[l iflU I.H BLOCK NO
|C..unlv fa :s>i ur Oll^hure a ea
HIG NO
ECTION lUWNSHIP. RAN(
STATt 'PRnviNCF
DRILLING ASSEMBLY
CASING
MUD VOLUME (BBU
CIRCULATION DATA
| ^ '7 X IN
TTFi-VEn.ATi !'OTA'L CIHCULATIN'G'vOLUW'i'f''1'^'"^^'. W?>DEL lAFSPMlo
•)H,:LP!pf iitPi
-•-'L
,N bK.'RAGE WEIGHT JB'BLET
.RiLL COLLAR <; jr
TYf't
BBL M!N
GAL WIN
AN',DLAR\EL .
DC
CIHCULA'iO\
IWSSURt |PS,
B!J TOMS
CP ir.'IM,
TOTAl CIRC
TIMF. [MINI
MUD PROPERTIES
Dt-ptn i ft>
Weight
Clastic Videos. ty cP
Or, b'renglh in 100 It'i • " sec 10 i
F UT-rlP API (cm' 30 mm )
At'' Ml MF' f .ll'.ilc Icni1 30 IT'in ,
--
Ca^t; 1F"Ckhe.L 32nd m AP, MIHP,
s Content ' Dy Vfl 1
I
Mflh> it;ne Biue CdpdC'l-, !h Lib' e-n
PH
SU'P
Mpter
Alt al.n,;^ Mud (Pn.)
lmilv Filtrate |P|
Allvnalr Alt.il n.ty FilUdle IP1 P2l
Chloride (rnq L]
lo Hardness ,lb Cjicium |mg I
1 F'
/
MUD PROPERTY SPECIFICATIONS
WLIGHT
VISCOSITY—,
FIITRATE
RECOMMENDED TOUR TREATMENT
REMARKS - Givt l^t-HAMON DtPIHANDNAf JRf Of AN Y PFiuBLE M S F NCC< JNttHtt)
EQUIPMENT _ .
DESANDER M"D CLEAN
DES1LTER UtbASbtH
HI SP SHAKER
DAILY COST
( • ' . .
CUMULATIVE COS'
(>984
-------
e HUGHES DRILLING FLUIDS
10777 N W Freeway Suite 700
PO Bo. 22753
(7131 680-3623
OPERA' on
REPORT FOR
)
\
WFLl NAME AND NO
DRIL
BIT SIZE
-••;/;,
/
URILL PIPE
SIZE
DRILL PIPE
SIZE
DRILL COLLAR
r~ '.
I .. .
LING ASSEMBLY
TYPE
JET SIZE
TYPE
TYPb
Slit
LENG
*H
LENGTH
LENGTH
fF\\
111 . DEPTH - -
£\S DATE " 19 ._ ..,-' v
A SPUD.DATE , PFrtSE.NT ACTIVITY
V J . -T{. f .
CONTRACTOR " ' RIG NO
i _ ~*
REPORT FOR SECTION. TOWNSHIP. RANGE
rC-,.'. '•• ' •-• i'\- •*'•-'
1 IELD OH BLOCK NO County F*ansh or Otfbhore area STATE PROVINCE
i : • i • '* '- •
CASING MUD VOLUME (BBL) ' CIRCULATION DATA
SURFACE HOLE PITS . i x IN ANNULAR VEL (FT MINI
PUMP
'-""-•• -' • */: SIZE ,2 " x - ' IN DP /' DC ' ''
INTERMEDIATE TOTAL CIRCULATING VOLUME PUMP MAKE MODEL ASSUMED C'RCUtATiON
„ ,-~ . Iff .- . PRESSURE (PSh / . . -
INTERMEDIATE IN STORAGE ' WEIGHT BBL STK STKMIN BOTTOMS
„ UP ;MIN] .-- , ; J
PRODUCTION
ft
OR LINER MUD BBL MIN GAL.MIN TOTAL CIRC
TYPE ,, , — / ,' .. TIME (MIN) J '., _- «••
MUD PROPERTIES
Sample From
1 line Sample T
a*er.
Fiowlme Temperature °
F
Depth |tl|
Weight v-
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MUD PROPERTY SPECIFICATIONS
WEIGHT . ' VISCOSITY.^ FILTRATE
RECOMMENDED TOUR TREATMENT
j' . / . ' *• , - ' -
C\ .-•••• <- :- s> -,-. .-' . /
/ . •', •
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REMARKS - G VF OHtRATION DEPTH AND NATURE Of ANY PROBLEMS ENCOUNTERED
~f " '
T-- ' ... / ' ' '/'-"'•
'' ;A ' '
////// EQUIPMENT
/ / / / / / DESANDER MUD CLEANER
UtblLltH UtGAiSER
r' HI-SP SHAKER ' CENTRIFUGE
'• - • DAILY COST
4} !.."•••- -. S" ^' c'
" - -• CUMULATIVE CObT
MOBILE PHONE ^ )v.HSE r^^Nr
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r^.oM—1 HUGHES DRILLING FLUIDS
1 MUOMMI ,077? N w Free»«y Su'le 700
bT^TflWHTB P 0 Boi 2rTf3
•^ [713)680-3823
OPERATOR
REPORT FOR
WELL NAME AND NO
\"-T . , :
DRILLING ASSEMBLY CASING
BIT SIZE /
DRILL PIPE
SIZE '.
'' r "
DRILL PIPE
SIZE
DRILL COLLAR
1 . -
TYPE JET SIZE SURFACE
TYPE LENGTH INTERMEDIATE
•a
TYPE LENGTH INTERMEDIATE
SIZE LENGTH PRODUCTION OR LINE R
||| DEPTH -
_£!,/ DATE 19 . • .
M SPUD DATE -f , PR£StNT
L^ ^j f
ACTIVITY —
CONTRACTOR RIG NO
REPORT FOR SECTION, TOWNSHiTSS
i/., •' /. •',-
MLLU UH bLUL'K NO Lounly. 'ansh or Offshore area SI AIt/PROV!NCE
.. • ' . f • i , "7*. , •
MUD VOLUME (BBL) CIRCULATION DATA
HOLE PITS pijMp , X IN.
*S ' ' -'/ . SIZE .2 /- X/'"'- IN DP
ANNULAR VEL. (FT/MI
• ' "DC
TOTAL CIRCULATING VOLUME PUMP MAKE. MODEL ASSUMED CIRCULAI ION
f > • .' f ET PRESSURE (PSI| ,
IN STORAGE WEIGHT BBL/STK STK.'MIN BOTTOMS
,- , UPIMIN, f- . *
• '''"'' ' ~'f -' '"'' /•' ^
MUD BBL'MIN GAl/VIN TOTAL CIRC
TYPE/ .-- , .- ,--, ..., (. ;. TIMEIMIN) ,^
MUD PROPERTIES
Sample From
T inie Sample T
aken
Flowlinfe Temperature °F
Depth III)
Weight i
Funnel ViscObi
-tppyi (Ib cu It ) Sp G
y isec qt» API « °F
Plastic Viscosity cP « ef
v ield Point Ub
100 ft')
Gel Strength (II) 100 If") 1 0 sec 10 mm
Filtrate API (err
1 30 mm |
API HTHP Filtrate lcm'-30 min )»/ °F
Cj*e T hicknes
Solid'. Cnntcnl
Liquid Content
Sund Content
132nd in API HTHP)
r\ by Vol ) calculated relitil
l-c by Vol 1 Oil'Watei
' . by Vol )
Methylene Blue Capacity Ib/bbl enuiv C"1J cm"1 mud
pH St
Alkalinity Mud
P Me er ,i °t
fir.]
Alkalinity Filtrate |P|.-<
' 'T
-• HI SP
DFR MUD CLEAN
ER DtGASSER
SHAKER CENTBIfUOE
DAILY COST
£j ( /;
CUMULAT
J
| / "/
MOB'Lt PHONE -WK
V'E cosi
SE ptojNt ^ ^
lOr' VV£;|T U'X'U Ri 'N ii.'."~. tit Nt-' 'i 1 ' ARE DCARF FULLY ANDN'.^BEt'^::" '"( nL
»i !"'.t.rryOOn d!' • ALI MS A', Id l'SCORRFCTN!c,f. Of.. C"Vi'untr'ISS •*
| '1 SM.".
-------
e HUGHES DRILLING FLUIDS
10777 N * Fr«awa> Su-l* 700
' (7131680-3823
OPERATOR
f-"\
REPORT FOR
WKl NAME AND NO
,
i
*• ^ DRILLING MUD REPORT NO.
71^ i
xl-^ IDATE ' .19
.M. sf'.IDDAlt PRESE
CONTRACTOR
Rtf'JPl FOR
^. - . ' - -
1 IELD OR BLOCr^ NO Liunty. u'i',n or Offshore area
\ — i \ ' • >•
DEPTH - x .._
NI ACTIVITY
•/ .'
RIG NO
SECTION TOWNSHIP. RANGE
' /
STATWPROVINCE
1 .
DRILLING ASSEMBLY CASING MUD VOLUME (B6L) CIRCULATION DATA
B.1SI7E. TY=L
"I'M t"- -
rjRIU PIPF TYPE
DRILL PIPE TYPE
OKl.l COLLAR SI^E
==^=^=^=^^^=^^=
S 30 mm // °F
CjkeThickntss 132nd in API HTHP/ .
Suhds Content l"i by Vol }
liquid Content I11, by Vol ! Oi
calculated ret irt
Water
S.md Content 1', by Vol )
Me thyiene Blue Capacity . Ib'bblequiv cmj cm' mud
PH Strip Meter B,,rjuci /-—•**/
".VENTORY /^-^jr<--.
I1 ACTING , . ,
'NVENTCRY ' ' ' / /
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CIRCULATION
PRESSURE (PSII
BOTTOMS
UP (MINI ^- -/
TOTAL CIRC
TIME (MINI /.~ .• "-*'
MUD PROPERTY SPECIFICATIONS
WEIGHT .'"' r-. VISCOSITY./
*.••>' '-<'''- 2^>
FILTRATED < _, ,
RECOMMENDED TOUR TREATMENT
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<-.' r- ; /• ; 1 _.- J.' ^ T/-
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REMARKS - GtVF OPEPAtlON DEPTH ANO NAT! .RE Of ANr PR(JjLr>* ENCCXNTtRED
> '' '
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////// EQUIPMENT
/ /"/~ / / / °!
I ' . L)l
v_ ' ; " : ' 7 - - -N ' ' H
^ DA,LY
/ '
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SANDER V'JD CLEANER
SILTER DEGASSER
SP SHAKER CENTRIFUGE
COST
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(—• — >| HUGHES DRILLING FLUIDS
MtKJt*H.» 1Q777 N W Freeway Suite 700
1.1 IIHI11*! PO Bo, 22753
OPERATOR
^' (7131680-3823
i/ '•} ^'-r
REPORT FOR
WELL NAMl AND NO
V-~ l . •
DRILLING* ASSEMBLY
BIT SIZE.
siz^r".
UR'LL PIPE
SIZE
DRILL COLLAR
T>PE JET SIZE
. \ -" - . ' .
TYPE LlNGTH
TYPE LENGTH
SIZE LENGTH
CASING
SURTACE
INTFRMC3IATE
if.'ERMEDiATE
.(/
PRODUCTION OR LINER
j\J DATE "7V 19 '''A '<' Y-,v
M. SPUD-DATE , . j HFTtSEptrACTIVITY —
CONTRACTOB HIGNQ.'1
/' ' * "i -'''
HtHOHUOH SECTION. TOWNSH?r\BA
1 • t ' 'T T • • ^ /
s. '. ' / • . i i
HELU UH BLUC*. NU Ci unty. Pd,' bli ui Ullb lute died bl Al t/HHOVINCE ~
< '- > . ' ' '/•.'. }'-•'•
MUD VOLUME (BBL)' CIRCULATION DATA "~
HOLE PITS PLMP " X IN ANNULAR VEL |FT,M
*•--/'• " *- ' S'ZE «2 /' X ''' IN DP /' ' DC
TOTAL CIRCULATING VOLUME PUMP MAKE . WoDEL ASSUMED CIRCUIA1ION ',
/ — ^, , J i Ef*-, . PRESSURE |PSI| p ,.,.
• /'• •'•'.'• "/ : % / ».••• :"
IN STORAGE WEIGHT P9L STK STK MIN BOTTOMS
UP (WIN) .-.-~ " ,
' ^ "*" •— i
MID BBL MIN GAL. MIN TOTAL CIRC
TYPE . , , • -, - -TV TIME (MINI /,..-,,-;
MUD PROPERTIES
tjjmple From
7. me Sample Tonen
F'.'.tw1 ne Temperature °F
Depth ittl
Weicjh:
r.,nnei V.ico,,
lung] l b cu it |
y .'bee qti API ., °F
S|. G
*''jMic ViscOMty cP ./ °F
v.fia Pomt (ib
•• 00 If
Ge Strength (It) IOC ft;| 10 sec 10 mm
' .I'rjle API {err
' 30 m n )
/. = ' HTHP Fim.rt (cn^'30 mm ) „ °F
Lj.e Itnckiitb
Solic^ Content
i32nd m API HTHP|
I' c by Vol I calculated ret
rt
„•'.! nd Content (u, bv vol 1 Oil Water
!jPI1
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'
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MUD PROPERTY SPECIFICATIONS
WEIGHT -f — , VISCOSITY f FILTRATE ^ "
ji i : * '
RPPOMMFMnFO TOt IR TRFATNVIFWT
• • ir - -. - , t >
,
l 'tin- e . f ,}!/-.. • , r -r " .'
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REMARKS - GIVE OPERATION DEPTH AND NATURE OF ANY PROBLEMS LNCOUNTSRID
/ •' ; -
\
////// EQUIPMENT __
/ / / / / / DESANDEfl MUDCLEA
£• 4 *- ^- <- DESILTER DEOASSEB
'• HI-SP SHAKER CENTfllfU!
— '' ' ' ' ' DAILY COST ,
^T / ?/ '_
CUMULATIVE COST
/*•"• -'"
|MOB' E PHONE IWHSE "h^Nc
.V?.«?».v.V:-rvv-: «.-;.«. • •,:.iU'7i?.-ir!;^.:^S
-------
e HUGHES DRILLING FLUIDS
10777 N W Fr«e«,at Suite 700
" (7131 toO-3823
III'IRATOR
fit PORT FOR
09
DATE "'-J -/'.' 19 •
&PUD DATE „ , PflE
^ -.;.". -:/
CUNIF(ACIOF(
f ' ''.
REPORT FOR
^j''';1 c /
WEU NAME AND NO FIELD OH BLOCK NO
DRILLING ASSEMBLY , CASING MUD VOLUME (BBL)
B:l S.ZE TYPE
J ' i - \ _ '.
DRILL PIPE TYPE
DRILL PIPE1 TYPE
SIZE
DRILL COLLAFi SIZE
j'ET SIZE | SURFACE HOLE PITS
'l ' • J - ' i '
LENGTH INTERMEDIATE TOTAL CIRCULATING VOLUM
LENGTH INTERMEDIATE IN STORAGE/ WEIGHT
•H
LENGTH F'RODUCTION OR LINER MUD
MUD PROPERTIES
Sdl;ple From
limr Sample T jnen
fiowlme Temperature CF
Deptnilt!
Weight uppgi b cu ft i SrG
1 V t' API
°f
PljStiC ViiCOVty CP a °F
> itld Pd.nt lib 1 00 tt;
GfSlrtngin ,b 100ltr) 1 0 sec 10 mm
ri!'',i!.' API (cm1 30 mm )
iP'HTHP Filtr.ile icm1 30 min 1 „ T
Calf lliickneM iS^nd in API HTHPl
Si. l.tlv Content ("! by Vol I calculated fi-tinl
Liquid Content i • by Vol | Oil'Water
Sand Content (^ by Vo 1
MdrVene Blue Capacity Ib bbl equw cm1 cm 'mud
r>H Strip ' Meter « °F
Alkj nit, Mvid |Pm)
Alkalinity Fillra e (Pi M(l
Chloride Img L)
lotai Hardness ,lv Calcium (mg/L)
F L ^fT
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DEPTH ,
SENT ACTIVITY
is .-•
RIG NO x.
SECTION. TOWNSHIP. RANGE
STATE, PROVINCE
CIRCULATION DATA
PUMP " * "
SIZE .2 /- X '" II
E PUMP MAKE. MODEL ASSUME
BBL.STK STK/MI
f / ' --
_, y/ • •'/ ' _^
BBL'MIN GAL. Ml
~"7 /' ">/^7
/ '• ' ~ , .'
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, DP /;- DC .-;••
D CIRCULATION
PRESSUFiE (PSII .- .. ^
N BOTTOMS
UP (MIN) ^ ,'j. ^
N TOTAL CIRC
TIME (MINI / - f^-^-
MUD PROPERTY SPECIFICATIONS
WEIGHT ,y
^
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REMARKS -G
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^LN'TOR, |/,;>- //
RECEIVED '
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r ANY PROBLEMS ENCOUNTERED
- ..^ /
EQUIPMENT
DESANDER MUD CLEANER
DESILTLH DLGAbSER
HI-SP SHAKER CENTRIFUGE
LY COST
, ' / "^~ —
^C LAf VE COST
H'vnSt PnONE
"•-..':•'•:."• r.SE/ ;^v.c.^
-------
r— — >i HUGHES DRILLING FLUIDS
1 MUOMK» j 107;; N w Ffotl,av Sul|c 700
^ ^ I'
3) 660-382J
OPERATOR
FUI'URT IOR
WELL NAME AND NO.
„
f~ . ^ DRILLING MUD REPORT NO. ~~ — •
.t|>/ DATE 19 •-
DEPTH
1 bPUD DATE PRESENT ACTIVITY' "^
CONTRACTpR
HEPOR/ FOR
' ' /
, - , , . • -J,-', f ' ->-,.• v—
FIELD OR BLOCK NO County, Parish or UUshore area
/ "^~! /;- 7 ; . i • • -. ' t ...
HIG NO T
9-*
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1
SECTION, TOWNSHIP, RA
""**''" -~\ —
!T~ ,
blAIE/PHOVINCE ~
T..
DRILLING ASSEMBLY CASING MUD VOLUME (BBL) UHUULAI ION DATA ~~~"
BIT SIZE TYPt
n -1;* -r-
DRIi-i. PIPE TYPE
SIZE . , /
Q~-
/
DRILL PIPE , i > r
S.ZE
DRILL COLLAR SIZE
JET SIZE SURFACt HOLE PITS PUMP " X IN
-'-.:-•,—' (,~i\,~ ^ '' SIZE '2 ''- x '\~~"*
LENGTH INTERMEDIATE TOTAL CIRCULATING VOLUME PUMP MAKE MODEL ASSUMED
'"' /J7!T ; .'/;.... "V---%
LENOTH INTERMEDIATE IN STORAGE WEIGHT BBL/STK STK.'MIN
. & * - .
LENGTH PRODUCTION OR LINER MUD BBL MIN GAL/MIN
•"•-, 11 TYPE ^ f A f^ — *-*>!>
MUD PROPERTIES
Sample From
Time Sample Taken
Flowlme Temperature °
F
Depth (ft)
Weight ^JOpfil
(lb;cu ft SpG
F'lastic Viscosity cP it
°F
°F
•\ .eid Point (Ib 100 ftr)
Gel Strength lib 100 ft') 1 0 sec; 1 0 m n
Filtrate API Icnv 30 mm.)
AP! HTHP Filtrate (cm3/30 mm
Cake Thickness (32nd
y. °F
n. API/HTHP)
Sol'ds Content IH by Vol ) £*«Stculated retort
1 iquid Content °o by Vol I Oil/Water
Sana Content (°i by Vol I
Methylene Blue Capacity Ib/bbl equiv. crrP/cm-1 mud
I'H f^l"^
: Meter u °F
Alkalinity Mud (Pm)
Alkalinity Filtrate (Pf'M|l
Ai'rmate Alkal mty Filtrate (P1/P2I
Chlnnde lmg>L|
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CIRCULATION '
PRESSURE (PSI|
BOTTOMS *
UP (MINI ,..
TOTAL CIRC
TIME (MINI /(I
MUD PROPERTY SPECIFICATIONS
WEIGHT _ VISCOSITY
7 . ~<
'/-
/ •' • •
REMARKS - GIVt OPERAT ON Of PTH AND NATURE OF ANY PROBLEMS ENCOUNTtflfO
' I '
1
////// EQUIPMENT
//////••"
.j Dt
•: HI
SANDER ./MJDCLE/
SILTER .'. DEGASSE
-SP SHAKER CENTRIFU
; 1" ! • • "< ' ' '• -> DAILY COST ,,
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-------
r~m Tl HUGHES DRILLING FLUIDS
HUOrm 10777 N W Fr«e»«y Suilf 700
^milfnTa PO Bo. 22753
^HJi*^' 1713)660-3623
OPERATOR
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REPORT FOR
WELL NAME AND NO.
*\ \ DATE w- • ^ 19 "•
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CONTRACTOR
REPORT FOR
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FIELD OR BLOCK NO County. Parish of Otfshore area
DWLLING ASSEMBLY CASING MUD VOLUME IBBLI CIRCULAT
BIT SIZE TYPE
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DP , ^1 ' y DC "^ / Ci
CIRCULATION
PRESSURE (PSI)
BOTTOMS
UP (MIN)
V/
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TIME (MIN)
MUD PROPERTY SPECIFICATIONS
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-------
r— — ^ HUGHES DRILLING FLUIDS
j Mum l»» j 10777N w f,,,wtf Su'le ?00
^*™-*— '" (7131 6SO-3823
OPERATOR
ITYV, *•<•
REPORT FOR
WELL NAME AND NO
7 —
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i-|X DATE ^'. / 7 19^6, J ,,,,•,
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HELD OR BLOCK NO County. Parish or Offshore area SI AH/PHUVINCE
DF&LING ASSEMBLY CASING MUD VOLUME (BBL) CIRCULATION DATA
BIT SIZE TYPE
DRILL PIPE TYPE
LI '/•) y ^4.
DRILL PIPE TYPE
SIZE
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£ '/£
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MUD PROPERTIES
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Weight Cfppgl
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Gel Strength (Ib. 100 (1
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Filtrate API |cmV30 mm I
API HTHP Filtrate lcm!
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Cake Thickness (32nd in API.'HTHP)
Solids Content (% by Vol ) ^**tculated ' retort
Liquid Content C*s by Vol ) Oil/Water
Sand Content (% by Vol )
Methytene Blue Capacity , Ib/bbl equiv "crrWcnVmud
pH (^ _SKtp
: . Meter rt °F
Alknln.ity Mud [Pml
Alkalinity Filtrate IPf.'Mt)
Alternate Alka mt>. hiltnte (P1/P2)
Chloride (mg'L)
Tetal Hardness as Calcium (mfl.'L)
PRODUCT /
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-------
/-——^ HUGHES DRILLING FLUIDS
1 mK***** J 10777 N W Fr««w«y Suile 700
•MJM^nH Houston, Texts 77227
OPERATOR
REPORT FOR
WELL NAME AND NO
f",-^., l-~Ci
DfiftLING ASSEMBLY CASING
BI! SIZE TYCE —
-!-% •*-£
DRILL PIPE TYPE
SIZE .,'
<-/ /,±-_ y H
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SIZE
DRILL COLLAR SIZE
JET SIZE SURFACE
LENGTH INTERMEDIATE
.ft
LENGTH INTERMEDIATE
•'./
LENGTH PRODUCTION OR LINER
( ' / "'
^ ^ DRILLING MUD REPORT NO.
/If DEPTH
±\S DATE -- .'„' 19^.^, ,/'-;?
M SPUD DATE_ PRESENT ACTIVITY ^
^* •"' . ^ — 5,? /"^i,-/-
CONTRACTOR RIG NO ~" C^-
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REPORT FOR SECTION. TOWNSHIP. RANGE
FIELD OR BLOCK NO County. Pa' sh or Ollshore area STATE/PROVINCE
~~A- --' '' i.-ff/.'-. ~'S
MUD VOLUME (BBL) CIRCULATION DATA
HOLE PITS . . „ . l X IN ANNULAR VEL. (FT'MIN)
PUMP
1 ^ , p' (4^-Q SIZE <2 / ^ / r—{N DP / ;,-; DC ~ / ff
TOTAL CIRCULATING VOLUME PUMP MAKE. MODEL ASSUMED CIRCULATION '
^ / EFF PRESSURE (PSII /
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MUD PROPERTIES
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Weight
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LIABILITY IS ASSUMED f OR AN1 DAMAGl SRESt'LllNiJfROM HI 1IM III '.AMI
-------
IHUOHES f|
UGHES DRILLING FLUIDS
777 N W Fre**8v Su le 700
D Bo« 227t3
uMon leias 77227
OPERATOR
ifcPORT FOR
WELL NAME AND NO
( jfvi
J-|>/| DATE , ; 19 •;•;„
DEPTH
I 1 SPUD DATE PRESENT ACTIVITY' ~~~^ —
L_ J ~. -I
CONTRACTOR
R! r-ORl FOR
FIELD OR BLOCK NO County. Pdnsh or Ollshore area
Kilo NQ ^_ —
SECTION luWNfHIP. RM
STATt'PROVINct
DMLLING ASSEMBLY CASING MUD VOLUME (BBL) CIKCULAI ION DATA ~"""~
BIT SIZE TYPE
DRILL PIPE TYPE
S'ZE , ,
DRILL PIPE TYPE
SIZE
DRILL COLLAR SIZE
-y JET S'ZE SURFACE HOLL- PUS PUMP* * IN
— * 1 .' / J - ' - -J *^ j ^±- ' • • / J
LENG.H " INTERMEDIATE TOTAL CIRCULATING VOLUME PUMP MAKE, MODEL ASSUMED
E,FF
/ '-"•,;-- /L' -«-<••: ?O 1=
LENGTH INTERMEDIATE IN STORAGE WEIGHT BBL/STK STK,MIN
LENGTH PRODUCTION OR LINER MUD BBL'MIN GAL, MlN
MUD PROPERTIES
Sdinple From
I iri»f Sample Taken
F Irwlme Temper j ure "
F
Depth |tt)
Weight WTppgl
(Ib cu tt ) Sp G
Funnel Viscosity tsec,'qt) API n °F
Plastic Viscos ty cP //
°F
Yield Point (Ib 100 ft1)
Ge1 Strength (lb'100 It
Filtrate API (cm3/30 m
API HTHP Filtrate cm3
;) 10 sec 1 0 mm
n 1
30 mm <, °F
Cake Thickness (32nd in. API-HTHP)
Solids Content (% by Vol ) ^fi^cutated . reJort
Liquid Content (% by Vol ) Oil'Water t
Sand Content (°D by Vol 1
Methylene Blue Capacity .. Ib/bb equiv cm3, cm3 mud
p^ ttrltf ' Meter g/ °F
Alkalinity Mud (Pml
Alka mity Filtrate (Pf'Mf)
Alternate Alka mity Filtrate (PI .'P2l
Chloride Img'Ll
Total Hardness as Calcium (mg L)
PRODUCT /
INVENTORY / <
STARTING
INVENTORY \~\fr
RECEIVED
IJSED LAST
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TOTAL CIRC
TIME (MINI
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r^lotmm\ HUGHES DRILLING FLUIDS
1 I**"^P J 10777 N W Frecwiv Suil* 700
irtTTffiT^J Houilon Ieiii772?7
^fl*"""^' (713) WO-3823
OPERATOR
_jv\u^x
REPORT FOR
WELL NAME AND NO
c C
^— — ^ DRILLING MUD REPORT NO.
ll II DEPTH
±1^1 DATE LI . - c. 1 9 ,-r-i. ' / ~7 / \"
J. f SPUDDATE^ PRESENT ACTIVITY
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REPORT FOR SECTION. TOWNSHIP RANGE
^ J O t- .^_ * 0 > 1 T: t-» — ^ -1
FIELD OR BLOCK. NO County. Parish or Oflshore area STATE 'PROVINCE
DULLING ASSEMBLY CASING MUD VOLUME (BBL) CIRCULATION DATA
B.TSZl TYPE
DRILL PIPE TYPE
SIZE ,
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DRILL PIPE TYPE
S'Zt
DHILL COLLAR SIZE
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LENGTW INTERMEDIATE TOT AL CIRCULATING VOLUME PUMP MAKE. MODEL ASSUMED CIRCULATION '
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NOllCf ANY OPINION ANP "h M CiA'V: '. .•.'..', L O'HU ' 1 L •••-..• -p^'QiQ' C, ••'• ' '. ••'-• •; I'M' ran[ D CARf ' • 'L t > AND VI i BF ' 'b( ' ;TH[uSEH
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LIABILITY is ASSUMED 'OR AN> DIMAC.! ••• ' i i«c 'F,> •/ • M i.;- . ..-.••
-------
ft.uatmM\ HUGHES DRILLING FLUIDS
1 MUOMKV 1077? N w Fr,.,.y Sulle 700
• .!:, Hl.'l J " 0 Bo, 22753
OPERATOR
REPORT FOR
i T" r
WELL NAME AND NO
31 MO- -823
VC 0
±\S DATE J ' : / 19^^,
UtPIH
/ . c. . P
A SPUD DATE _ PRESENT ACTIVITY ' •
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CONTRACTOR
REPORT FOR
FIELD OR BLOCK NO County. Parish or Offshore area
HILi NO. ^
7
SECTION. TUWNSHIP. RANg
STATE/PROVINCE '
DRIULING ASSEMBLY CASING MUD VOLUME (BBL) CIHCULAIION DATA '"""
BIT SIZE
DRILL PIPE
SIZE , ,1
DRILL PIPE
SIZE
DRILL COLLAR
c
TYPE
TY~PE
TYPE
SIZE
__ JET SIZE j SURFACE HULE PITS p[JMp . 1 X IN
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LENGTH INTERMEDIATE TOTAL CIRCULATING VOLUME PUMP MAKE. MODEL ASSUMED
® S/6s ^ SJ* E"
LENGTH INTERMEDIATE IN STORAGE (WEIGHT BBL7STK STK/MIN
LENGTH PRODUCTION OR LINER MUD - BBL/MIN fiAL/MIN
MUD PROPERTIES
Sample From
T ime Sample Taken
Flowlme Temperature °
F
Depth (Ml
Weight ^
'rt>pgl
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Funnel Viscosity Isec'qt) API // "!
Plastic Viscosity cP if
Yield Pomt (Ib
I 00 ft1
"F
Gel Strength (Ib/ 100 H't 10 sec- 10 mm
Filtrate API (err
V30 mm.)
API HTHP Filtrate Icm1
Cdke Thickness (32nd
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n. API/HTHP)
Solids Co-item (% by Vol.1 ^Mfculated retort
Liquid Content
(% by Vol I Oil/Water <
Sand Content (°-o by Vo )
Methylene Blue Capacity L^lb/bbl equiv. L cmj cm3 mud
PH (^^
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r . Meter « °F
Alkalinity Mud (Pm)
Alkannity Filtrate (Pf/Mf)
Alternate Alkalinity Filtrate (P1/P2I
Chloride (mg'L)
Total Hardness as Calcium (mg/L)
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TIME (MIN) /(""J
MUD PROPERTY SPECIFICATIONS
WEIGHT VISCOSITY f
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f~~~: T\ HUGHES DRILLING FLUIDS
HUOrm^l JQ777 n w Fr*«way Suite 700
•niffiEHW Houston 7e*as 772?7
^•*"*™^- (713) 680-3823
OPERATOR
Jl\ i r-x
REPORT FOR
Will NAME AND NO
r f I
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DRILLING Ml ID RFPORT NO
T¥"V
IB 1 DEPTH
±|>/ DATE ' .' .P. 19."-. 'XVV
^ SPUD DA1E PRESENT ACTIVITY
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Solids Content (% by Vol.1 ^e*e"ulated : retort
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Sand Content ("t, by Vol 1
Methylene Blue Capacity . . Ib/bbl equiv cm3 'cm3 mud
p^ "tSlntf"
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Alkalinity Mud (Pm!
Alkalinity Filtrate |P|/Mfj
Alternate Alka mity Filtrale (P1/P2I
Chloride Img'L)
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-------
Sampling Report
Investigation of Chevron USA, Inc.'s
W. V. Lister No. 1 Gas Well Production Facility
Wheeler County/ Texas
June 24, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Anadarko Basin production sites developed by the
Texas Railroad Commission at the request of EPA. The list was
transmitted via telephone to the EPA contractor on June 16,
1986. Randomization and site selection took place during the
telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Railroad Commission listed the possible sample sites by
operator and specific location. For simplicity of selection, the
list was transmitted as shown below. The list consisted of five
Anadarko Basin production sites:
1. Chevron USA - Wheeler County
2. Cities Service Oil and Gas
3. Chevron USA - Hemphill County
4. Mobil Production Tex. & Mex.
5. Mobil - Hemphill County
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 1 on the above list
(Chevron USA). No. 5 on the above list (Mobil Oil - Hemphill
County) was selected as a back-up site in the event the primary
site was inaccessible or inappropriate.
Further inquiry identified the primary sample site as Chevron
USA Incorporated's W. V. Lister No. 1 Gas Well Production
Facility in Wheeler County, Texas. The back-up site was not
required.
C-999
-------
Site Location
The location of the Chevron USA Lister production facility is
approximately eighteen miles northeast of Shamrock, TX via
highways 83 and 592 in Wheeler County. Figure 1 is a map
indicating the production facility site. The full name and
mailing address for Chevron USA is:
Chevron USA, Incorporated
P.O. Box 1462
Pampa, TX 79066-1462
Main Office Ph.: 806-665-1614
Main Office Contact: R.B. Eckerdt, Senior Production
Foreman, Pampa Group
Attendees
Sampling at the Chevron USA Lister production site was performed
by CENTEC Corporation personnel on June 24, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (Sample Team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
State Representative: Frank Groves, Geologist,
Railroad Commission of
Texas, Oil and Gas Division
Operator Representatives: R.B. Eckerdt, Senior
Production Foreman, Pampa
Group
J.T. Harris, Assistant
Production Foreman
American Petroleum Institute
Representative: George Holliday, Contracted
Observer
Site Description
The Chevron USA Lister production facility is located in a rural,
flatland area. The climate at this site location is net
evaporation. The soil is described as sandy loam. The site is
located over the Hunton formation of the Anadarko basin.
The depth to the groundwater in the area is 15 feet. The nearest
surface water is located 1/2-half mile from the site. The
surface water is a creek that receives only rain water runoff so
that it runs intermittently. There is one 40-foot drinking water
well located 2,400 feet from the site.
C-1000
-------
Figure 1. Location of Chevron, Inc.'s W. V. Lister #1 Gas
Well Production Facility, Wheeler County, Texas
C-1001
-------
The site consists of one gas well, a series of gas processing
units, two produced brine tanks, and one evaporation pit.
Figure 2 is an approximate schematic diagram of the facility,
indicating the directions in which photos were taken (Attachment
A) . The produced brine tanks had never been cleaned as of the
time of sampling. These tanks are open to the atmosphere at the
top (Photo 7), and are made of fiberglass. The brine tank that
was sampled has been in use since 1974.
At the time of sampling, there was one producing gas well on the
W. V. Lister lease. This well produced daily quantities of
approximately 1 million standard cubic feet of natural gas, and 4
to 6 barrels of brine. The well depth is 20,965 feet.
The lined pit onsite was designed as an evaporation pit for
produced brine. Brine is piped to the pit from the brine tanks
such that the brine tanks usually remain one-fourth full (roughly
2,000 barrels). At the time of sampling, the depth of liquid in
the pit was approximately 1 foot, and the depth of the sludge was
1/4 to 1/2 foot. The pit has a fiberglass liner that is 50-65
millimeters thick. The pit area is completely fenced in, as
shown in Photos 1 and 3.
Disposal Practices
Produced brine is disposed of at the Chevron USA Lister produc-
tion site by evaporation from open storage tanks and a pit
designed for this purpose. Solids that collect in the pit are
sometimes used to fill pot holes in roads located on the lease.
Permits
A copy of the evaporation pit permit is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Chevron USA Lister site, the produced fluid sample was
collected from one of the brine tanks that feed the evaporation
pit. Figure 2 indicates the sample point from which the fluid
sample was taken.
Sampling Methods and Equipment
As shown in Photos 7 and 8, the fluid sample was obtained from
the open top of the eastern brine tank. The depth of the brine
in the tank was measured as 7 feet, 2 inches. Thief volumes were
C-1002
-------
Ptvte i.
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Figure 2. Schematic of Production Facility
C-1003
-------
taken at depths of 1, 3, 5, and 7 feet below the surface, and
composited in a 5-gallon glass carboy (Photo 8).
Brine from the upper three depths was very clear and colorless,
but brine from 7 feet below the surface was black and full of
flaky particles. The operator suggested that this might be due
to dust blowing into the top of the tank and settling to the
bottom.
The pH of the produced fluid sample was tested onsite after
sampling was completed. The pH was 7 for this sample.
C-1004
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1005
-------
C-1006
-------
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Photo 1. Southwesterly view of production site
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Photo 2. Southwesterly view of production site
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Photo 3. South end of evaporation pit
-------
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Photo 4,
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Westerly view of production unit (left) and
we I I head (right)
'Photo 5. "Production pack"
-------
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Photo 7. Thief and gauging tape over
top of brine tank (right)
Photo 8. Sampled brine tank (right)
and liquid composite (left
of sampler)
-------
Photo 9. Southwesterly view of brine tanks
Photo 10. Southeasterly view of brine tanks
-------
ATTACHMENT B: PERMITS
C-1011
-------
C-1012
-------
RAn-ROAD COMMISSION OF
OIL AND GAS DIVISION
MES E. (JIM) NUGENT, Chtirmui
^CK WALLACE, CommU«ioner
ARK JOBE, Commiwioner
JIM MORROW, P.E
Director
JERRY W. MULLIGAN
Director of Underground
Injection Control
01 N. CONGRESS
CAPITOL STATION — P. O. DRAWER 12967
AUSTIN, TEXAS 78711-2967
PERMIT TO MAINTAIN AND USE A PIT
Pit Permit No. P004539
Chevron U.S.A. Inc.
P.O. Box 1660
Midland, Texas 79702
Based on information contained in your application (Form H-ll) dated
October 24, 1984, you are hereby authorized to maintain and use the pit
designated herein:
Type of Pit: Saltwater Disposal Pit
Lister (057750) Lease. Well #1
1UUU teet HNL and 11UO feet PEL of Section 2, B.B.B. & C. RR. Survey
Wheeler County, RRC District 10
Authority is granted to maintain and use the pit in accordance with
Statewide Rule 8 and subject to the following conditions:
1. Use of the pit is limited to disposal of produced water from the
Lister No. 1. No other oil field fluids or oil and gas wastes may be
stored or disposed of in the pit.
2. The capacity of the pit may not exceed 12,000 barrels.
3.
4.
5.
6.
7.
At least 2 feet of freeboard must be maintained between the fluid
level in the pit and the top of the pit dikes.
The pit must be lined with a fiberglass liner with a thickness of at
least 50 mils.
The liner must be installed in accordance with the
manufacturer's specifications and sound engineering practices.
liner
The pit must be equipped with a leak detection system to detect leaks
in the liner.
If the leak detection system indicates liner failure, the
District Office must be notified of that fact within 24 hours of
detection of liner failure.
An Equal Opportunity Employer
-------
Permit No. P004539
Page 2
8. If the leak detection system indicates liner failure, the liner must
be inspected for deterioration and leaks within 10 days of detection
of liner failure. After inspection, the liner must be replaced or
repaired before resuming use of the pit.
9. The permittee must maintain a record of when the liner is inspected
and the results of each inspection. This record must be maintained by
the permittee for the life of the liner, and, upon request of the
Commission, the record shall be filed with the Commission.
10. No oil may be allowed to accumulate on top of the water stored in the
pit. Any oil on top of the water must be skimmed off.
11. Unless otherwise required by conditions of this permit, construction,
use, and maintenance of the pit shall be in accordance with the
information represented on the application (Form H-ll) and
attachments thereto.
12. A sign shall be posted at the pit which shall show the pit permit
number in numerals at least one inch in height.
13. The pit must be dewatered, backfilled, and compacted within 120 days
of final cessation of use of the pit. Final closure of the pit must
be accomplished in such a manner that rainfall will not collect at the
pit location after pit closure. Upon final closure, the
District Office shall be notified in writing.
14. This permit is nontransferable without the consent of the Commission.
Any request for permit transfer should be filed with the Director of
Underground Injection Control.
15. This permit does not authorize the discharge of any oil and gas wastes
from the pit.
This authorization is granted subject to review and cancellation should
investigation show that such authorization is being abused.
APPROVED AND ISSUED ON July 18, 1986
erground Injection Control
C-1014
-------
UTAH
C-1015
-------
C-1016
-------
Sampling Report
Investigation of Meridian Oil Company's
Navajo-Federal Well No. 23-4
San Juan County, Utah
June 29, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the Technical Report
(EPA 530-SW-87-005), with the changes noted below. This site was
originally planned to be selected randomly from a list of active
Paradox Basin drill sites developed by the Utah Department of
Natural Resources - Oil, Gas, and Mining Division at the request
of EPA. The list was to be developed just prior to June 29,
1986, the scheduled sampling date. The short time frame was
deemed necessary because of the uncertain progress of drilling in
this area. It would be impossible to plan the sampling of an
appropriate drill site more than a day or two in advance.
Randomization and site selection were to take place a few days
before sampling.
On June 25, 1986, the Department of Natural Resources notified
the EPA contractor that it was unable to locate more than one
drill site at or near completion for sampling. The single
available appropriate site is considered a random sample because
it was the only site known in the desired basin during the
necessary time frame. No bias was introduced into the selection
of this site. It was selected on the basis of availability. No
information was available to indicate this site was an
appropriate site for sampling.
The site was identified as Meridian Oil Company's Navajo-Federal
No. 23-4 in the Paradox Basin. No problems were encountered
arranging for sampling the Meridian drill site on June 29, 1986.
Site Location
Navajo-Federal Well No. 23-4 is located 6 miles east of Hatch
Trading Post. Figure 1 is a map indicating the drilling site.
The site is operated by Meridian Oil Company, whose mailing
address is:
PO Box 1855
Billings, MT 59103
Contact Name: Bill Brown
C-1017
-------
Figure 1. Location of Navajo-Federal Well #23-4,
San Juan County, Utah
C-1018
-------
Attendees
Sampling of Navajo-Federal Well No. 23-4 was performed by CENTEC
Corporation personnel on June 29, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representatives:
Operator Representative:
American Petroleum
Institute Representatives:
Bruce Hoskins, Team Leader
Andy Procko, Engineering
Manager, Acting Technician
Dorothy Swindel, Utah Dept. of
Natural Resources; Oil, Gas &
Mining Division
Dan Jarvis, Utah Dept. of
Natural Resources; Oil, Gas &
Mining Division
Monty Phillippi, Meridian Oil
Maurice Jones, Contracted
Observer
Bob Zahray, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
Site Description
Navajo-Federal Well No. 23-4 is located within the Paradox Basin
in an area characterized as rural plateau. The depth to
groundwater is over 100 feet, and the nearest surface water is
over 2 miles distant. There are no drinking water wells within a
1-mile radius of the site. The soil in this area is sand. The
climate at this site is net evaporation.
This site was a developmental oil drilling site. Drilling was
being completed on the day of sampling. The well was at a depth
of 5,600 feet. Drilling was accomplished with fresh water muds.
The well was drilled on Federal land.
Figure 2 is a schematic diagram of the drilling site. One pit
was constructed for the site. The exterior pit dimensions were
160 feet long by 100 feet wide. Interior pit dimensions were 150
feet long by 50 feet wide. The pit was constructed to be used as
a reserve pit. There were no special pit construction require-
ments. Leak detection was not required. The pit was unlined and
had no special preparation prior to use. The pit received
drilling muds and trash. The pit area was fenced. The pit
construction was below grade. Photos 1 and 2 (Attachment A) show
the pit from the north side. Photos 3 and 4 show the pit from
the south side. The pit was dry on the day of sampling. The
C-1019
-------
Figure 2.
Schematic Diagram, Navajo-Federal Well No. 23-4
C-1020
-------
sludge depth in the pit was 2 feet. The total volume of
drilling fluids in the reserve pit was estimated to be less
than 2,500 bbl.
There was no storage of diesel oil at this site.
Disposal Practices
At the conclusion, all remaining drilling fluids were placed in
the reserve pit. There was no testing of pit contents. There
was no treatment of pit contents. The pit fluids were not
removed for final disposition. The liquid was evaporated. The
dried pit solids were buried. The pit site was reclaimed by the
addition of topsoil and reseeding.
Permits
The permit for this facility was submitted by the operator under
confidential status to the Utah Natural Resources Department.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The sample collected at Navajo-Federal Well No. 23-4 consisted of
one reserve pit sludge sample. Figure 3 shows the sampled pit
and the location of the sample points. Four quadrants were
established for sludge sampling. There was no discrepancy
between measured and actual sample points.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants and to locate the center of each
quadrant. The sludge was sampled with a Teflon-lined coring tube
by wading into the pit at the designated locations.
Due to travel constraints, the samples were held overnight in
refrigeration prior to shipment to the laboratories. The samples
were shipped by courier to the overnight mail service, resulting
in a 2-day interval between shipment and laboratory receipt.
C-1021
-------
N
fARTH \>\KF
EARTH DIKE
56'
PC)
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1023
-------
C-1024
-------
Photo 1. Reserve pit, north side
Photo 2. Reserve pit, north side
Photo 3. Reserve pit, south side
Photo 4. Reserve pit, south side
-------
C-1026
-------
ATTACHMENT B: PERMITS
C-1027
-------
C-1028
-------
The facility drilling permit is being
held under Confidential Status by the Utah
Natural Resources Department until April, 1987
C-1029
-------
C-1030
-------
Sampling Report
Investigation of Marathon Oil Company's
Tin Cup Mesa Well No. 1-25
San Juan County, Utah
June 30, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected from active
Paradox Basin production sites accessible to the sampling team
from a drill site being sampled by the EPA contractor nearby (see
the trip report for Meridian Oil Company's Navajo-Federal 23-4
well). The Utah Department of Natural Resources - Oil, Gas, and
Mining Division identified this site at the request of EPA. Site
identification was transmitted via telephone to the EPA
contractor on June 25, 1986.
No back-up site was selected. No problems were encountered
arranging for sampling to be conducted June 30, 1986. No back-up
site was required.
Site Location
Tin Cup Mesa Well No. 1-25 is located 6.5 miles northeast of
Hatch Trading Post, Utah. Figure 1 is a map locating the
production site.
The site is operated by Marathon Oil Company, whose mailing
address is:
602 North Washington
Cortez, CO 81321
Contact Name: Jim Vangilder
Attendees
Sampling of Tin Cup Mesa Well No. 1-25 was performed by CENTEC
Corporation personnel on June 30, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representatives:
Bruce Hoskins, Team Leader
Andy Procko, Engineering
Manager, Acting Technician
Dorothy Swindel, Utah Dept. of
Natural Resources; Oil, Gas,
and Mining Division
Dan Jarvis, Utah Dept. of
Natural Resources; Oil, Gas,
and Mining Division
C-1031
-------
Figure 1. Location of Tin Cup Mesa Well #1-25, San Juan
County, Utah
C-1032
-------
Operator Representatives: Jim Vangilder, Production
Foreman
Bill Doyle, Marathon Oil
American Petroleum
Institute Representatives: Maurice Jones, Contracted
Observer
Bob Zahray, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
Site Description
Tin Cup Mesa well No. 1-25 is located within the Paradox Basin in
rural foothills; the depth to groundwater is over 100 feet, and
the nearest surface water is over 2 miles away. There are no
drinking water wells within a 1-mile radius of this site. The
soil in this area is mostly rock. The climate at this site
location is net evaporation.
This site consists of actively producing oil wells with a
production of 900 bbl/day. Daily production of produced water is
180 bbl/day. Production at this site is sweet. The well depth
is 5400 feet. The well produces using water flooding. The lease
for this well contains a total of four producing oil wells, one
dry hole, and one shut-in well. Figure 2 is a schematic diagram
of the production facility- The site around Well No. 1-25
consists of eight oil stock tanks, a heater treater, and two
brine tanks. The tanks at this site are cleaned only when
designated by site personnel. The emergency pit at the base of
the brine tanks had never been used.
Disposal Practices
The produced water is disposed by reinjection for enhanced
recovery. Well No. 1-25 had been drilled in 1981 as a producing
oil well. In 1985, it was converted into a produced water
injection well. Prior to injection of the water, biocide at the
concentration of 1 gallon to every 6 barrels of water, is added.
The cost of the biocide is $97/day.
Permits
Well No. 1-25 operates under Permit No. 43-037-30690. Attachment
B contains a copy of the permit to convert the well into an
injection well along with an injection report and the original
drilling permit. Attachment C contains the drilling program, and
surface plan for the well issued in 1981.
C-1033
-------
I7O'
ISO'
e'Heoter-l
Treater I
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RESERVE PIT.
(FILLED IN)
I
-------
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The sample collected at Tin Cup Mesa Well No. 1-25 consisted of
one liquid sample. The sample was collected at a sample port
from one of the pumps that reinject the water from the brine
tanks. Photos 1 and 2 (in Attachment A) show the sampling
location.
Sampling Methods and Equipment
The sample bottles were filled directly from the sampling port of
the reinjection pump. A test for pH of the produced water were
conducted onsite after completion of the sampling. A pH value of
7 was obtained for the water.
Samples were shipped by courier to the overnight delivery
services, resulting in a 2-day interval between sample shipment
and arrival at the laboratories.
C-1035
-------
C-1036
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1037
-------
C-1038
-------
Photo 1. Sample collection location
Photo 2. Sample collection
C-1039
-------
C-1040
-------
ATTACHMENT B: PERMITS
C-1041
-------
C-1042
-------
=i\/ED
FoenTOGC-3
STATE dF UTAH
JUN 1 / l-fcrWARTMENT OF NATURAL RESOURCES
DIVISION OF OIL, GAS, AND MINING
lSio.s OF Ut.
SUBMIT IN Dl\ -,CATE*
(See other instructions
on reverse side)
5. LEASE DESIGNATION AND SERIAL X
U-31928
OR RECOMPLETION REPORT AND LOG *
6. a INDIAN, ALLOTTEE OR TRIBE NAME
TTTYPE or WELL: o.^ D ^L D .» H r.,H., Tnjprtinn
b. TYPE OF COMPLETION:
MEW I—I WORK I 1 DEEP- I 1
WELL I I OVER LJ EN LJ
S17»..D
Convert to
other _lLU£c±iniL_
7. UNIT AGREEMENT NAUI
Tin Cup Mesa
2. NAME Or OPERATOR
Marathon Oil Company
S. FABM OR LEASE NAME
Tin Cup Mesa
3. ADDRiai OF OPERATOR
P.O. Box 2659, Casper, Wyoming 82602
9. WELL NO.
1-25
4. LOCATION or WELL (Report location clearly and in accordance with any State requirement!)*
«»*«• SW NW 1950' FNL & 790' FWL
it top prod. Interrtl reported below
At total depth
10. P1ELD AND POOL, 01 WILDCAT
Tin Cup Mesa
11. SEC., T., R., a., OH BLOCK AND SCBVEY
OR AREA
Sec. 25. T38S. R25E
14. PERMIT NO.
DATE ISSUED
43-037-30690 I 6-29-81
12. COUNT! OR
PARISH
San Juan
Utah
19. DATE SPUDDED
7-18-81
16. DATE T.D. REACHED
8-15-81
17. DATE COM PL. (Rtady to prod.)
Convert to Inj!'13'8'
18. ELEVATION* (DP. RKB, RT, OR, ETC.)*
4985' GL, 4999' KB
19. ELET. CASINOHEAD
20. TOTAL DEPTH, MD A TVD
5714'
21. PLUO. RACK T.D.. MD * TVD
5540'
22. IT Ml LTIPLE COM PL.,
HOW MAM*
23. INTERVALS
DRILLED BT
ROTART TOOLS
CABLE TOOLS
5714'
24. MODUCINO INTERVAL(S), Or THIS COMPLETION—TOP, BOTTOM, NAME (MD AND TVD)*
Previous Producing Interval - Ismay 5416'-5426'
Injection Interval thie Comp1etion-5454'-5473' & 5434'-5438' Ismay
25. WAS DIRECTIONAL
SURVEY MADB
No
29. TTPE ELECTRIC AND OTHER LOGS RUN
No logs run for this injection conversion
27. WAS WELL CORED
5 Cores •
2S.
CASING RECORD (Report all itringt let in veil)
CASINO SIZE
9-5/8"
WE10HT. LB./TT.
36#
DEPTH SET (MD)
1557'
HOLE SIZE
12-1/4"
CEMENTING RECORD
640 sx
AMOUNT PULLED
None
JLL
23# & 26#
5712'
8-3/4"
995 sx
None
tt.
LINER RECORD
30.
TUBING RECORD "
TOP (MD) ROTTOM (MD) SACKS CEMENT* SCREEN (MD)
DEPTH SET (MD) PACKER SET (MD)
2-7/8"
5346'
5346'
h. FliroRATiON RECORD (Interval, me and number)
Previous: 5416'-5426' 4 JSPF
This completion: 5454'-5473; 5434'.
5438' 4 JSPF
S2.
ACID. SHOT. FRACTURE, CEMENT SQUEEZE. ETC.
DEPTH 'INTERVAL (MD)
5416'-5426'
5434'-5473'
AMOUNT AND KIND Or MATERIAL CSED
First-Acidized with 1500 gals.
15% HCL
Second-Acidized with 1200 gals.
15% HCL
33.'
PRODUCTION
"ATI riRST PRODUCTION
^iniP^tinn 1-11-'
MTI or TUT
5-9-85
i»w, nnwo PRBS.
InJ. 3300 PS I
'«. DiiposmoN or o
PRODUCTION METHOD (Flotoina, aai lift, pmtptna —
-------
FORM OOGM-UIC-J
(Rule 1-5 (b) 2
(Reviled 1982) (To
DEP,
APiun 43-037-306?
040 A»*i
N
•
•>
I
•ntf Otilluw LMM
L^ TYPE CO
Single Z<
Multiple
Coming!
LOCATION 1
ba tiled within 30 day
MTMENT OF NATURA
)0 DIVISION OF Oil,
Room 4741 Sla
Soh late a
COUNTY San
COMPANY OPEI
OFFICE ADDRESS
TnuiM Caopci CTATI Tl» ni _ ULUUL
t oftor drilling li com
L RESOURCES AND 1
GAS. AND MINING
le Office Building
ly, Utah 64114
Juan$ec.25_
ATiun Ma rath
PLEASE TYPE OR US
ri.,.j, U-31928
COUNTY
ENERGY UAUNO.
Dn Oil Comoanv
P.O. Box 2659
<-r.n» i.i v oocno
FARMMAMf Tin Cup Mesa wmwo 1-25^
— 7 i ft
DRILUNO STARTED '"lo |
DATE OF FIRST PRODUCTION
WELL LOCATED .
690 n FI
ELEVATION DERI
MPLETION
.„ Ismay
H
XCEPTION
NEu SW
lOMSLOFK
(ICK FLOOR .
^ OIL OR GAS ZONES
t^ Nama
*»•
Ismay
From T*
5416' 5482'
a8* nil
iiiunnKiitucn 8-15,o81
8-28-81 mMW«m 1-26-83
u NW
u
4999
' r..n,,Mn 4985'
RLCU^bU
JUN 1 7 1385
DIVISION Ul- Ok
rfOIH^
From T*
CASING A CEMENT
7 Coilng Sot
^ Si..
9-5/8"
7"
Wgl.
36
23&26
Grade Foal
K-55 1557'
K-55 5712'
Csg. Test
Pil
1500
3000
Sam
640
995
Cement
Flllup Tap
Surface
1520' CBL
Tnr&t MVTH R 7 1 4 ' K R
E BLACK INK ptMLY
COMPLETION A TEST DATA BY PRODUCING FORMATION
t 3 3
FORMATION
SPACING A SPACING
ORDER NO.
CLASSIFICATION
(DISPOSAL WELL, ENHANCED
RECOVERY, IP GAS STORAGE)
PERFORATED
INTERVALS
ACUMZED7
FRACTURE TREATED?
INITIAL TEST DATA
Data
Oil, bbl./doy
CHI Gravity
Gai, Cu. Fl./doy
Gat-Oil Rail* Cu. Ft./BW.
Watar-BU./day
Pumping or Hawing
CHOKE SIZE
Pumping
KtBWUUBJNO PRESSURE
A record of the formatron
Please Refer t
Ismay
Unit Well
Enhanced
Recovery
5416'-5426'
Please See
Attachment
1-26-83
30
45°
53.000 °
1767
37
Pumpinq
None
50 PSIG
CF
CF
• drilled through, and pertinent remarks are presented on the reverse.
(use reverse side)
o Attachment
1, the undersigned, being fin! duly iwom upon oath, state that Ihli well record !• true, correct and complat
according to the recordi of thl> office and to the belt of my knowledge and belief
(307) A /7C/I
¥.Upl 577-1555 ^J/^Jf^ Jforw^, District Production Mgr
Sub«crib*d and mwom before
(/ *tafr* ond '"'• "* roproMnlodvo of company
ftfter Injection Conversion Packer set at 5346"
KB
-------
C, C
ATTACHMENT
FORMATION TOPS
Shinarump
Moenkopi
Cutler
Honaker Trail
Paradox
. U. Ismay
Hovenweep
L. Ismay
Gothic Shale
Desert Creek
Chimney Rock
Akah
PRODUCTION
2,276'
2,339'
2,384'
4,229'
5,164'
5,322'
5,485'
5,515'
5,565'
5,573'
5,673'
5,695'
TREATMENT
The Ismay Perforations 5416'-5426' were acidized with 1500 gallons of 15%
HCL acid.
TREATMENT DURING INJECTION CONVERSION
The Ismay Formation was perforated at 5454'-5473' and 5434'-5438' with 4
JSPF.
All perforations 5416'-5473' were then acidized with a total of 2700
gallons of 15% HCL acid.
2-7/8" tubing was landed in the packer set at 5346' KB.
;UN i ? J385
OFQ/L
IG
C-1045
-------
R25E
23
PROPOSED INJ. WELL
M.O.C.
TIN CUP MESA 3-23
^ M.O.C.
™ TIN CUP MESA
2-23^
24
EVAPORATION POND
/ M.O.C. I
M.O.C.
TIN CUP MESA 1-23
M.O.C.
TIN CUP MESA 3-26
26
25
M.O.C.
TIN CUP MESA 4-26
TANK
BATTERY
TIN CUP MESA
UNIT
PROPOSED INJECTION
PRODUCING
DRY
WATER SUPPLY
-PROPOSED WATER
(JSUPPLY WELL
PROPOSED INJECT!
M.O.C.
TIN CUP MESA 1-25
o o o
" o o o
M.O.C.
TIN CUP
MESA
2-25
M.C.O.R
3-26-84
W.WEST
C-1046
-------
V
SUB JUT IN TfctrtJCATZ*
fona approrH.
Bndctt Borcan tfo, 42-8:1123
UNITED STATES ' ™~ -«•>" "
DEPARTMENT OF THE INTERIOR
GEOLOGICAL SURVEY
APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK
ltTffi°rW°" DRILL D DEEPEN D PLUG BACK D
k, -an or wm,
on, in «AB r— i STROU r-i ntnnnj i— i
linu liJ wiu. LJ OTHim ZOKB 1 1 rosi l_l
I IAKI or oriBAioa
Marathon Oil Company
J, AfiOUtt 0V OPCatATOB
P.O. Box 2659, Casper, Wyoming 82602 '
4. MCATIOII or wau. (JUport location dtmrlr and la aeeordaaca wltn any 3tata> reqainnjcata.* )
41 ""*"* 1950' FNL & 790' FWL JWNW_
it pro pond prod. i»n«
6h miles northeast of Hatah Trading Post, Utah
5. ULLBB OailOMATIOJI AJTD **•<•'. 30.
U-31928
7. (7arz Aa&nMazrr AA^I
S. rABJi oa r.ina .IAKB
Tin Cup Mesa
». wau, .10.
1-25
10* Ttl^O AJ1D fOOlX OB ^ILOCxC
11. aac. r, i_ x_ OB ILX.
AflD BCBTBI OB '»"
Sec. 25, T38S, R25E
12. COO.TTT OB PAAI1S 15. dTATI
San Juan Utah
U. autAirci no* raoroaao* IS. -•«>. or Acxaa Uf L&UB IT. no. or ACUS USUHID
UMATION TO .1KABUT TO THI1 WIU.
noniTT oa uuaa LUC, rt. inn i -r/-« i AM
(Aln u DMmc dri«. oalt Ua*. If aarl 790 760 80
18. DUTAUCt nOH ?aoroan> LOCATION* 19. raoroaao DBRB • u. 20. BOTABX oa CAJLX TOOL*
TO KHaisr WILL. oaiLu.ia. connjTto, n^A*
OB ATTUB. POB. o» ma LCAS. rr. ^One 5840' fr**^ Rota>V
O. HHABOMB (Show whitlMr OP. ST. GS. «to.) 22. Arraoz. DAXB woax WILL STABT*
4985' GL 1st Half of 1981
PBOPOSEO CA3ING AND OntEHTOJO PROGRAM
im or HOU
Please see' It
ana or CA>IHO
em #4 of 10 Poi
WBICHT raa roor
nt Program -for
scmnc DCPTV
complete Casim
O.OAWTTTT or CSKC.TT
r & Cementing Program
Please see the following attachments:
1. Surveyor's.PI at
2: Ten-Point Drilling Program
3. BOP Schematic
4. Thirteen-Point Surface Plan
5. Maps & Diagrams
n
\J
DIVISION Or
Ci'L. GAS & MlNf.VQ
i* ABOTI arACi paacaiaa rioroaia MOOBAM : If proposal la to devpco or pine back, girt data on pment prednctlr* iont aad propooil arw pro
MM. If propoial U to drill or d««pea dlrtctloiuUj, »!T« pertinent data OB rabiuitac* location! and measured Bad tm« vertleal deptn*. Glre blowoat
' protraa. If any.
.,„„
District
Ooerations Manaqer
2-3-81
(Tail jpaet for Fcdiral or State oj&ft a**)
iprmoTAL OATB .
COHMTIOIII or'ArraovAL. IT AST
OPERATOR'S COPY
BY TH
TE
C
-------
c
c
"COMPANY HA3A*reCN OIL COMPANY
L£ASK
TIN CUP KESA
WELL NO.
1-2$ —
sec.
SAN JUAN COUNTY, UTAH
VOCATION 1950 TNI 790'FJL
ELEVATION ti985 ungraded ground
.
-- —
.
—~
. __ _ __.. _
•
o
XT
790 « J
I
T '
1 ..
I
_
L
I
y '
' i Sec.
1
i
I
1
1
I
"1
1
1
1
1
1 .
_ ...I.
l
_ J
.1
• i
r
. 4
i
i
-.
i
1
i
i
i
i
>i
c\
*CALC—4 INCHES EQUALS 1 MIUE
THIS IS TO CERTIFY THAT THE ABOVE PUAT WAS PREPARED TROM
riELO NOTE OF ACTUAL SURVEYS.6*A~DE BY ME UNDER MY SUPER.
VISION ANO THAT THE SAME AR~E TRUE ANO CORRECT TO THE
BEST OF MY KNOWLEDGE ANO BELJEF. . '. '.
•EAUl
•URVCYEO
#3950
R*e'rtcr*d Land Surwyor.
80
C-1048
-------
ATTACHMENT C:
DRILLING PROGRAM AND SURFACE USE PLANS
C-1049
-------
C-1050
-------
MARATHON OIL COMPANY
DRILLING OPERATIONS PLAN
DATE: January 28, 1981 "
WELL NAME: Tin Cup Mesa--#l-25~ ~" -
LOCATION: 790' FUl-4-1950' FNL, Sec.-25, T38S, R25E, San Juan Co., Utah
1. Geologic name of the surface formation:
Jurassic Morrison "Formation -"Brushy 3asin Shale" Member
2. Estimated tops of important geological markers:
Formation
Carmel
Nauajo
Kayenta
Wingate
Chinle
Shinarump
Cutler
Honaker Trail
Datum
—779*---
805'
1,024'
1,199'
1,549-'
2,353'
2,459'
4,273'
"(•*~4»216^t
(+ 4,190')
(+ 3,971')
(+ 3,796')
<+ 3,446')
(+ 2,642')
(+ 2,536')
(+ 722')
Formation
"Paradox ~
Upper Ismay
Hovenweep Shale
Lower Ismay
Gothic Shale
Desert Creek
Chimney Rock Shale
Akah
T.D.
Datum
5,241'
5,398'
5,559'
5,591'
5,641'
5,655'
5,743'
5,764'
5,840'
(- 246')
(- 403')
(- 564')
(- 596')
(- 646')
(- 660')
(- 748')
(- 769')
(-.345')
3. Estimated depths at which oil, water, gas or other mineral
bearing formations are expected to be encountered:
Formation
Carmel
Navajo
Wingate
Dechelly
Paradox
Upper Ismay
Lower Ismay
Desert Creek
Depth
1,
5,
5,
779'
80S1
199'
*
241'
398'
5,591'
5,655'
Possible Content
Water
Water
Water
Brine
Brine
Oil - Primary Objective
Oil - Secondary Objective
Oil - Secondary Objective
C-1051
-------
DRILLING OPERATIONS PLAN"A
PAGE TWO
4. the Proposed Casing Program:
Casing Design
CASING
STRING
Conductor
Surface
Production
HOLE
SIZE
20"
12-V
8-3/4"
8-3/4"
8-3/4"
INTERVAL
0'-60'
0'-1,550'
0'-1,050'
1,050 '-3, 900'
3,900'-5,840'
SECTION
LENGTH
60'
1,550'
1,050'
2,850'
1,940'
Cement Program:
SIZE
(OD)
16"
9-5/8"
7"
7"
7"
9-5/8"
WEIGHT, GRADE
AND JOINT
Thinwall Steel
360, K55 STC
26#, K55 STC
23/F, K55 STC
261? , K55 STC
Casing
MEW
OR
USED
New
New
New
New
New
MUD
WEIGHT
NA
8.6.
13.0
13.0
13.0
1,0000
TENSION
LOAD
NA
55.8
143
116
50
SFt
NA
7.58
2.54
2.66
7.22
SEc S£b
NA NA
2.73 5.25
5.04 1.35
1.14 1.26
1.09 1.75
CM
in
o
Cement Volume: 1,550' x .3132 cu.ft./ft. x 2.0 excess = 970'cu. ..ft.""
Lead Slurry: 1,000' calculated plus 100% excess - 340 sacks of high yield cement (BJ Lite,
Lite, etc.) containing 1/4 Ib/SK cellophane flakes and 2% CaCLo.
Slurry Yield: 1.84 cu.ft./SK
Slurry Density: 12.7 Ib./gal
Water Requirement: 9.9gal./SK
Halliburton
Tall Slurry:
550 ft. calculated plus 100% excess
cellophane flakes and 2% CaCLo.
Slurry Yield: 1.18 cu. ft./SK
Slurry Density: 15.6 Ib./gal
Water Requirement: 5.2gal./SK
- 300 sacks of class "B" cement containing 1/4 Ib./SK
Casing Equipment:
Guide shoe, differential fill collar, 3 centralIzers. WOC time will be a minimum of
6 hours. If float equipment holds, closed-ln pressure after completion of cement job
Is not recommended.
i
o
-------
MARATHON OIL COMPANY
' DRILLING OPERATIONS PLAN
PAGE THREE
Cement Program: (Cont.)
7" Casing
1st Stage
Cement Volume: 2,840 ft. x .1503 cu. ft./ft. x 1.20 excess = 512 cu. ft.
. Slurry: 2,340 ft. calculated plus 20% excess from logs - 434 sacks of
Class "B" cement containina 0.32 fluid loss additive (D-19,
Halacl 9, etc.)
2nd Stage -• - ~ ~ -- -
Cement Volume: 2,000 ft. x .1503 cu. ft./ft. x 1.2 excess = 360 cu. ft.
Slurry: 2,000' calculated (500' into 9-5/8" casing) plus 2.0% excess
from logs - 235 sacks of high yield cement (BJ Lite, Halliburton
Lite, etc.)
Casing Equipment: Locate stage collar 3,000'. A guide shoe, flapper type
float collar, 1 cement basket, and 10 centralizers
spaced over the bottom 800 ft. of hole will be used.
If float holds, closed-in pressure after completion
of cement job is not recommended. Set casing on
slips as soon as possible following cement job.
Slurry Preflush: 1st and 2nd stage 20 bbls.
5. Pressure Control Equipment:
BOP equipment will include a double-ram type preventer with pipe and blind
rams and a rotating head (API arrangement SRDA). All equipment will have a
3,000 psi or greater working pressure. Rams, valves, lines, choke manifold
and casing will be tested to 200 psi for 5 min. and 1,000 psi for 5 minutes
prior to drilling out from under 9-5/8" surface casing. After drilling
casing shoe and 5 ft. o.f additional hole, a shoe test will be performed to
13.5 ppg equivalent mud weight or leakoff, whichever occurs first. The
accumulator should be of a sufficient capacity to meet the following re-
quirements:
1. Ability of immediate closure to all members of the stack
without recharging.
2. A total of 50% of the original fluid should remain as a
reserve after accumulator activation.
3. A minimum pressure of 1,200 psi is required to insure
that the preventers remain closed.
Visual checks of the equipment will be made tourly. Function pipe rams
daily and blind rams on trips.
C-1053
-------
' • MARATHON OIL COMPANY
DRILLING OPERATIONS PLAN
PAGE FOUR
6. Drill ing Mud Program:
From To Type Mud Weight % Oil Hater
• •
0' 1550' Spud 8.5-9.0 0 No Control,.,
1550' Cutler (2500') gel/water 8.5-9.0 0 No Control1'
Cutler (2500') Upper Ismay (5400') gel/chemical 9.4-10.3 0 10.0-12.0c
Upper Ismay (5400') T.D. gel/chemical as required 0 3.0- 9.0c ,
fli
Mud weights should be kept to a minimum to maximize ROP and minimize lost cir-
culation. However, the existence of water flows may necessitate an increase
in mud weight while drilling. Sufficient barite should be on location prior
to spud in order to increase mud weight to 12.5 if required. Lost circulation
is expected in the upper hole before setting surface casing.
7. Auxiliary Equipment Required:
A drilling rate recorder, calibrated to record drilling time for each one foot
interval will be used.
The mud system will include a desander/desilter, gas buster or degasser.- A
manual choke will be used.
A kelly cock will be used and a full opening manual safety valve will be avail-
able on the rig floor.
A single shot drift indicator will be used.
Flow sensors and pit level monitors will be installed in the mud system.
Deviation Control: ... _. , „ . _ . . . u . ru,n^
Maximum Distance Maximum Deviation Maximum Chang
From To Between Surveys From Vertical Per 100' of De
0' 1,550' 250' ' 1° 1°
1,550' T.D. 500' 5° 1°
Slight deviation problems in general area.
3. Testing, Logging, Coring and Fracing Program:
Samples: 10 ft. interval from 1,550' to T.D.
Logging: 1. DI - SFL/GR - Surface to T.D.
2. RHC SON1C/GR - Surface to T.O.
3. FDC/CNL-GR From 4,000' to T.D.
Testing: 1. Upper Ismay
2. Lower Ismay
3. Desert Creek
Coring: Approximately 350 foot core to include Upper Ismay, Lower Ismay and
Desert Creek
C-1054
-------
MARATHON OIL COMPANY
DRILLING OPERATIONS
PAGE FIVE
Fracing Program:
The productive intervals will be stimulated by acidizing with 2,000 gallons 28% HC1
acid and if necessary will_be.acid_fractured._with 1,500 gallons 28%_HC1 acid..
Anticipated abnormal pressures or temperatures:
The Dechelly Mbr. of the Cutler FM., if penetrated, may contain overpressured
saltwater requiring 11.0 - 12.3 ppg mud weight to control.
%
Maximum anticipated bottom hole pressure is approximately 2,500'.
Maximum anticipated bottom hole temperature is approximately 175°F .
The anticipated starting date and duration of operation:
Starting Date: 1st half 1981
Duration: — -3d days
Name
^ ./ x/: (. .. S* \
Title Dril 1 ing Superintendent'/^:^//./CUtf.f.?:)*^*-J
t/ if
Date
C-1055
-------
KILL LINE
Casing Head
11" 3,000 x 9-5/8"
S/0 w/2 - 2" IPO
Tin Cup Mesa 11-25
790' FWL. 1.950' FNl.
Section 25, T30S, R25E
San Juan County, Utah
r. ••:
Hydraulic date Type
Blowout Preventers
3,000 ps1 MP
Adjustable Choke
1. Olowout preventers, master valve, plug valve and all fittings
must be tn good condition. Use new AIM Seal Rings.
2. All fittings (gates, valves, etc.) to be of equivalent
pressure rating as preventers. Valves to be flanged and at
least 2" unless otherwise specified. Valves next to OOP to
be plug type and nominal 3".
3. Equipment through which bit must pass shall be as large as
the Inside diameter of the casing that Is being drilled
through.
4. Safety valve must be available on rig floor at all times
and with proper connections. The I.D. of safety valves
should be as great as 1.0. of tool Joints on drill pine.
5. Kelly safety valve Installed, same working pressure as OOP's.
6. All lines and controls to preventers must be connected and
tested before drilling out of surface pipe.
7. OOP's must be fluid operated, complete with accumulator.
Controls may be either on floor or ground near steps from
rig floor.
8. Gauge will be Installed for testing but renewed while
drilling.
9. Spool not required, but when side outlet on OOP's is used,
it must be below bottom rain.
10. Caslnghead and caslnghead fittings to be furnished by
Marathon Oil Company.
Positive Choke
9-5/B", 36.01, K55
Casing to 1550'
-------
MARATHON OIL COMPANY
SURFACE USE 4 OPERATIONS PLAN
DATE: February 3, 1981
WELL NAME: Tin Cup Mesa #1-25
LOCATION: 1,950' FNL & 790' FWL, Section 25, T38S, R25E, San Juan County, Utah
S\ Existing Roads:
A. Proposed well site as staked. (Actual staking should include
two each 200-foot directional reference stakes).
See survey plat.
B. Route and distance from nearest town and locatable reference
point to where well access route leaves main road.
6-1/2 miles northeast of Hatch Trading Post, Utah.
See map diagram "A", color coded red.
C. Access road(s) to location color-coded or labeled.
See map diagram "A" color coded Green.
D. If exploratory well, all existing roads within a 3-mile radius
(Including type of surface, conditions, etc.).
' See map diagram "A".
E. If development well, all existing roads within a 1-mile radius
of well site.
Not applicable
F. Plans for improvement and/or maintenance of existing roads.
Blade and gravel where needed.
12 Planned Access Roads:
Map showing all necessary access roads to be constructed or recon-
structed, showing:
(1) Width 16'
(2) Maximum grades 0 - 9X
(3) Turnouts None required
(4) Drainage design Ditched and crowned, trailer ditches
where needed.
(5) Location and size of culverts and brief description of any major
cuts and fills.
None anticipated
(6) Surfacing material
Gravel
(7) Necessary gates, cattleguards, or fence cuts.
No cattle guards or fence cuts will be required.
(8) (New or reconstructed roads are to be center-line flagged at
time of location staking).
All new access road is center!ined flagged with Hot Blue and Hot
Orange flGgglrftSmeterial. The access was walked 50' on each side
by Archeologist from the University of Utah. See man diagram "A"
-------
f
MARATHON OIL COMPANY
SURFACE USE & OPERATIONS PLAN
PAGE TWO
13 Location of Existing Wells:
Two-mile radius map if exploratory, or 1-mile radius map 1f
development well, showing and identifying existing:
(1) Water wells "" None
(2) Abandoned wells None
(3) Temporary abandoned wells None
(4) Disposal wells None
(5) Drilling wells MCOR fl-25
(6) Producing wells None
(7) Shut-in wells None
(8) Injection wells None
(9) Monitoring or observation wells for other resources.
None
14 Location of Existing and/or Proposed Facilities:
A. Within 1-irrile radius of location show the following existing
facilities owned or controlled by lessee/operator:
(1) Tank Batteries None
(2) Production Facilities None
(3) Gathering Lines None
(4) Gas Gathering Lines None
(5) Injection Lines (Indicate 1f any of the above lines are burled).
None
(6) Disposal Lines None
B. If new facilities are contemplated, 1n the event of production, show:
(1) Proposed location and attendant lines by flagging 1f off of
well pad.
Adjacent to the access road and as close to the proposed
drill site as possible, without setting on any fill.
See diagram "B".
(2) Dimensions of Facilities
See Diagram "B".
(3) Construction methods and materials:
Good engineering practices will be used in the construction
of these facilities and materials will be obtained through
local vendors and contractors.
C-1058
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MARATHON OIL COMPANY
SURFACE USE & OPERATIONS PLAN
PAGE THREE
B. If new facilities are contemplated, in the event of production, show:
.- (cont'd)
(4) Protective measures and devices to protect livestock and wildlife.
Woven wire fences of the pit areas and flagging, if necessary.
C. Plans for rehabilitation of disturbed areas no longer needed for
operations after construction completed.
Restoration of the drill site and tank battery areas will be
reshaped to conform with the topography. The top soil will be
redistributed at the proper time. The sites will be reseeded
as per the recommended seed mixture.
#5 Location and Type of Water Supply:
A. Show location and type of water supply either on map or by written
description.
A water hole will be made on the down stream side of Cross Creek.
Approval was given by Jennifer Head, BLM, Monticello, Utah, to
Walt West, MOC. See map Diagram "A", color coded blue.
B. State method of transporting water, and show any roads or pipelines
needed.
Existing roads and access road will be used to haul water to location.
' See map Diagram "A", color coded blue.
C. If water well 1s to be drilled on lease, so state. (No APD for
water well necessary, however, unless it will penetrate potential
hydrocarbon horizons).
No water supply well will be drilled.
16 Source of Construction Materials:
A. Show information either on map or by written description.
Construction materials will be native soil or purchased from
a Jobber and hauled to the well site by same.
B. Identify 1f from Federal or Indian Land.
None
C. Describe where materials, such as sand, gravel, stone and soil
material, are to be obtained and used.
Any needed materials will be purchased from a Jobber and hauled
to the well site.
D. Show any needed access roads crossing Federal or Indian Lands
under Item 2.
None
#7 Methods of handling Waste Disposal:
Describe methods and location of proposed containment and disposal
of waste material, including:
(1) Cuttings Reserve Pit
(2) Drilling fluids Reserve Pit
(3) Produced fluids (oil, water) Swab Tanks
C-1059
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r
MARATHON OIL COMPANY
SURFACE USE & OPERATIONS PLAN
PAGE FIVE
#10 Plans for Restoration of Surface: (cont'd)
(3) Prior to rig release, pits will be fenced and so maintained
until cleanup.
The reserve pit will be fenced on 3 sides during drilling.
At the completion of the drilling, all pits will be fenced
on the one remaining side.
(4) If oil on pit, remove oil or install overhead flagging.
If there is oil on the reserve pit, it will be removed or
flagged with overhead flagging.
(5) Timetable for commencement and completion of rehabilitation
operations.
Depending upon climatic conditions, restoration should be
completed from six months to one year after abandoning well.
#11 Other Information:
General Description of:
(1) Topography, soil characteristics, geologic features, flora and fan
Topo is sagebrush, scrub cedars, covered hills, occasionally dlssi
by drainage features.
Flora is sagebrush, wheat grass and short stubby native grasses.
Fauna 1s deer, rabbits, fox, small rodents, cattle and sheep.
(2) Other surface use activities and surface ownership of all involved
lands.
The drill site and access road is owned by U. S. Government.
Attached are: Affidavit, Designation of Agent, Letter from
(3) Proximity of water,'occupied dwellings, archeological, historical
- --or cultural sites. There is a recent (30-40 yrs) HoganJype Sheepit
shelter In ruins, 152' NW of the center stake. It was decided by
Larval Casjens, Archeologist, Univerfsty of Utah, and Walt West of
HOC, not to disturb. There is no water or occupied dwellings In t
Archeological Clearance for the drill site and access road was glv
112 Lessee's or Operator's Representative:
Mike E. Krugh
Marathon Oil Company
P.O. Box 2659
Casper, WY 82602
(307) 235-2511 Office (307)
to be in "J "
113 Certification: The following statement is to be incorporated in
the plan and must be signed by the lessee's or operator's field
representative who is identified in item No. 12 of the plan:
I hereby certify that I, or persons under my
direct supervision, have inspected the pro-
posed drill site and access route; that I am
familiar with the conditions which presently
exist; that the statements made in this plan
are, to the best of my knowledge, true and
correct; and, that the work associated with
the operations proposed herein will be per-
formed by Marathon Oil Company and Its
contractors and subcontractors in conformity
with this plan and the terms and conditions
under which it is approved.
Date Name
Dri111ng Superintendent
.uper
Title
C-1060
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MARATHON OIL COMPANY
SURFACE USE 4 OPERATIONS PLAN
PAGE FOUR
#7 Methods of Handling Waste Disposal: (cont'd)
(4) Sewage Porta Pot
(5) Garbage and other waste material (Trash pits will be completely
contained with small mesh wire to prevent wind scattering trash
before being burned or buried).
There will be a 10' x 10' bum pit on the drill site, and
1t will be fenced.
(6) Statement regarding proper cleanup of well site area when rig
moves out.
At the completion of drilling, the site and surrounding area
will be cleaned up and all burnable material will be put in
the bum" pit and burned. All foreign material will be buried.
#8 Ancillary Facilities:
Identify all proposed camps and airstrips on a map as to their
location, area required and construction methods. (Camp center
and airstrip center lines to be staked on the ground).
None planned.
#9 Well site Layout:
A plat (not less than 1" - 50') showing:
(1) Cross sections of drill pad with cuts and fills.
See Diagram "C".
(2) Location of mud tanks, reserve, burn and trash pits, pipe
racks, living facilities and soil material stockpiles.
•• See Diagram "D".-
(3) Rig orientation, parking areas and access roads.
See Diagram "D".
(4) Statement as to whether pits are to be lined or unlined.
(Approval as used in this section means field approval of
location. All necessary staking of facilities may be done
at time of field Inspection). A registered surveyor is
not mandatory for such operations.
The reserve pit will not be lined and will be in the cut.
See Diagram "C".
110 Plans for Restoration of Surface:
State restoration program upon completion of operations, including:
(1) Backfilling, leveling, contouring and waste disposal;
segregation of spoils materials as needed.
The drill site will be cleaned and waste material will be put
in the trash burn pit, which will be covered at the finish of the
/„% drilling operation. The.reserve pit will be backfilled as soon as it is
(2) RevegetatTOn and rehabilitation - including access roads ^r
(normally per BLM recommendations).
The top soil will be redistributed and at the proper season
the seed mixture of BLM requirements will be drilled planted.
C-1061
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Pr6|racml Ac<
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VICINITY MAP FOR
MARATHON OIL COMPANY *1-25 TIN CUP MESA
195O FNL 700 FWL Sec. 25 T38S-R25E
SAN JUAN COUNTY, UTAH
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-1970
^oWW
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170'
130'
6' Heater
Treater
!D
Tin Cup Mesa #1-25
C SWNW Sec. 25, T38S, R25E
1950' FNL & 790' FWL
San Juan Co., NM
4985' GL
3O'x6'
Seperator
3OO BBL
Tanks
O
o
SCHEMATIC
of
PRODUCTION FACILITIES
Scale A 50'
PROPOSED
ISO
-------
170'
130'
ft! I I I
Parking Area
cm cm
Traitors
Scale l"=50'
\V~\6fiOPOSED
DIAGRAM\-J :
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170'
-Ditch or
Fire Wall
ISO'
IN ALL PROBABILITY THIS WELL'
JILL BE ACIDIZED ONLY
Tin Cup Mesa #1-25
C SWNW Sec. 25, T30S, R25E
1950' FNL & 790' FWL
San Juan Co., NM
4985' GL
RESERVE PIT
150'
\
DIAGRAM
FRAC LAYOUT
Sfcale l"=50'
"Proposed
-10'
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c
Dv..-'":i.>vnoN OK ACKI
Supervisor, Oil and Gas Optralions:
Tlie undersigned is, on the rt-cordj, of the Geological Survey,
Unit Operator undc-r the Crinvon Junction unit agreener.t,
San Juar. Couf.iy, Utah (state),
No. t approved anj
hereby design^ts:
NAME: Marathon Oil Company --—
ADDRESS: Box_120,_Casper,_ Wyoming 82602
as its agent, with full authority to act in its behalf in c cap ly ing with i
the terms of ths '.'-.it Agrecrer.t and regulations applicable thereto and «t
whom the suptrviscr or his representative rray serve written or oral ins:;
tions in securing r.or.plianr.c with the Oil. and Gas Operating Regulations
with respect to drilling, testing, and completing unit veil No.
in the SW fe NW fc Sec. 25 T. 38S • , R. 25E . ;
San Juan County, Utah .
It is understood that this designation of agent dots not relisv
the Unit Operator cf rorpcnsibiiity for co-pi iance uith the terms of the
uniL dgret;ntr.c u.r..\ Lhu Gil aiiu Cab Operating Regulations. It is also
understood that this desigr.ii.ion of agent does not constitute an assign-
ment of any interest under the unit agreement or any lease committed
thereto.
In case of default en the part of the designated agent, the
Unit Operator will make full and prompt, compliance with all regulations,
lease terms, or orders of the Secretary of the Interior or his representa-
tive.
/
The Unit Operator agrees promptly to notify the oil and gas
supervisor of ar.y charg" ir. the oOiignatfid ffgtnt.
•
This designation of agent is deemed to be temporary and in no
manner a permanent arrangement.
This designation is given only to enable the agent herein
designated trs drill the above-specific-.' unit well. Unless sooner ter-
minated, this designation «.iull terminate wnen there is filed in the
appropriate district office of '.he U. S. Geological Survey a completed
file of all required Federal reports pertaining to subject well. It is
also understood that this designation o£ agent is limited to field
operar.ions and does not ccyer administrative actions requiring specific
authorization of the Unit Operator.
MCOR Oil and Gas CornqratiorL
^ -V- go W. qfa^k Saul, Vice President
C-1068
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(
AFFIDAVIT
STATE OF WYOMING )
) SS.
COUNTY OF MATRONA )
The undersigned, being first duly sworn on oath, deposes and says:
1. That affiant is over 21 years of age and in all respects legally
competent to make this affidavit.
2. That affiant on the 22nd day of January, 1981, personally
examined the following described lands in San Juan County, State of Utah,
to-wit:
Township 38 South, Range 25 East. S. L. M.
Section 23: Wj, WHSE1;
Section 25: SWsUVfi.
Section 26: Eh
(Containing 760.00 acres, more or less.)
3. That affiant on said day made a reasonable effort, in connection
with such examination, to ascertain whether any person or persons were in
actual possession of or engaged in the working of the lands above described;
that no person or persons were found to be in actual possession or engaged
1n the working of said lands or any part thereof; that, as a result of such
examination, no evidence was found of any location monuments that could have
been used in locating placer or lode mining claims; that no evidence was
found of any mines or mining operations, open pits, diggings, shafts, holes
or other evidence of mining claims, and no indications of the performance
of assessment work on said lands; that no drilling well or wells for the
purpose of producing any mineral was found on said land; and that affiant
found no buildings on said lands, or structures, telephone lines, electric
lines, pipe lines, railroads, or other improvements thereon, except the
following:
Marathon Tin Cup Mesa well 11-25 is located 1950' from the north
line and 790' from the west line of Section 25, T.38S., R.25E.,
S. L. M., San Juan County, Utah. The proposed well site can be
reached by traveling from Hatch's Trading Post northeast on paved
road for approximately tv/o miles, thence on a gravel/dirt road
through two wash crossings and two cattle guards in a northeasterly
direction for approximately six miles to the west line of Section 25,
thence turning a left or in a northerly direction continuing for
approximately one-half mile to the well location.
The overall terrain is a mixture of high cliffs and rolling grassy
canyons. There are numerous seismographic trails throughout the
area. The hilly areas are covered with prairie grass, sagebrush and
buck brush. There are several artesian wells in the area, some of
which drain into shallow washes only a few inches deep. The SW corner
survey marker of Section 26 was located, along with the marker common
to Sections 26 and 35 mid point. A rock marker was found and is
believed to be the SE corner survey marker of Section 25.
A well being drilled by MCOR Oil 1 Gas Corporation was located in the
NPsSWs of Section 25. A fence was found running on the west lines
of Sections 26 and 23. There are no other fences, utility lines or
improvements of any kind in the area. The survey markers were clearly-
marked with flags for purposes of locating the well site. No mining
activity was apparent in this area. If any exists, they must be
hidden or out of the area.
i^LTl,
STEVE DEGENFILDE3
and sworn to before me on this 2. (a1^ day of hA .vi . . 1981
Expires:
C-1069
-------
sfiid ESas Corporation
EquitaDle Building. Suite 410. 730 17th Street. Denver. Colorado50202/Teiephone(303)893-5111
January 19, 1981
Mr. James Youngflesh
Marathon Oil Compan-
P,0. Box 120
Casper, Wyoming 82602
Dear Jim:
Further to our recent telephone conversation this is to advise
that we are at present using Hay Hot Oil owned by a Mr. Wright
for our water on our #1-25 well in San Juan County, Utah. Mr.
Wright is obtaining the water from the Cross Creek.
Also, your Right-of-Way request has been forwarded by this office
to Wexpro in Salt Lake City, Utah. You should shortly be receiving.
_this diroctlv from them. Allow about another week and if you have
not received the same from Wexpro, please advise.
Very
MCOR/Oil and Gprs Corporation
RSBtdm
RaymonH3S<7 Blunk
DistricVAandman
C-1070
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r
STIPULATIONS
Well sign should read:
Marathon Oil Company
U-31928
No. 1-28 Tin Cup Mesa
SWNW 25-38S-25E
San Juan County, Utah
This location may be potentially valuable for underground mining.
_ *••• ••• •»•.*• w. <• •
U. S. Geological Survey
Mining Branch
2040 Administrative Bldg.
1745 W. 1700 South
Salt Lake City UT 84104
C-1071
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c
STIPULATIONS
Well sign should read:
Marathon Oil Company
U-31928
No. 1-25 Tin Cup Mesa
SWNW 25-38S-25E
San Juan County, Utah
***NOTE: Items crossed out either do not apply or are already covered in
the operator's SUP.
Construction:
1. The operator or his contractor will contact the San Juan Resource
Area Office in Monticello, Utah (phone (801) 587-2201) 48 hours
prior to beginning any work on public land.
2. The archaeological site (Navajo hogan) on the west edge of the
location will be fenced and avoided during construction, rehabilitatio
and production operations. All employees working in the area will
be informed by the operator that they will be subject to prosecution
if they are caught disturbing archaeological sites or picking up
artifacts. If subsurface cultural material is exposed during
construction, work in that spot will stop immediately and the San
Juan Resource Area Office will be contacted.
3. Existing access will be used per our pre-drill discussion. Improvement
to the seismic trail will be limited to a total disturbed width of
18 feet including slope cuts, waterbars, drainage ditches and
running surface. The location of new construction will follow the
seismic trail. Sandy areas along the access road will be stabilized
with water.
Surface disturbance and vehicular travel will be limited to the
approved location and approved access route. Any additional area
needed must be approved in advance.
Surfacing material will not be placed on the access road or location
without prior BLM approval.
C-1072
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4. The location will be laid out and constructed as discussed during
the pre-drill conference and as indicated on the attached sheet.
5. Trees and brush removed from the location will be stockpiled on the
north edge of the pad.
6. The top six to eight inches of soil material will be removed from
the location and stockpiled separate from the trees on the west
edge of the drill pad for use during reclamation. Topsoil along
the access will be reserved in place.
7. A trash pit will be constructed near the mud tanks with steep sides
and dug at least six to eight feet into solid undisturbed material.
Trash will not be disposed of in the reserve pit. The trash pit
will be totally enclosed with a fine mesh wire before the rig moves
onto the location.
8. An inspection of the reserve pit will be made by USGS and/or BLM
after the pit is constructed to determine if lining will be necessary,
9. The reserve pit fence will be kept in good repair while the pit is
drying.
10. A burning permit will be required before burning trash between May
1 and October 31. This can be acquired by contacting the State
Fire Warden, John Baker at (301) 587-2201.
11. The dirt contractor will be furnished with a copy of these stip-
ulations and a copy of the operator's Surface Use Plan prior to any
work.
Rehabilitation
1. Immediately on completion of drilling, the location and surrounding
are will be cleared of all debris resulting form the operation.
ATI foreign material will be disposed of in the trash pit.
2. The operator or his contractor will contact the San Juan Resource
Area BLM Office in Monticello, Utah (phone (801) 587-2201) 48 hours
prior to starting rehabilitation work that involves earthmoving
equipment and upon completion of restoration measures.
3. Before any dirt work to restore the location takes place, the
reserve pit must be completely dry and any trash it contains must
be removed to the trash pit. The trash pit will not be filled in
until recontouring work begins and will remain fenced until that
time.
4. All distrubed areas will be recontoured to blend with the natural
topography as discussed during the pre-drill conference.
c-1073
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c
5. The stockpiled topsoil will be evenly distributed over the disturbec
area.
6. All disturbed areas will be scarified with the contour to a depth
of four to six inches.
7. Seed will be drilled during the fall months with the following seed
prescription.
3 Ibs/acre Indian ricegrass (Oryzopis hymenoides)
2 Ibs/acre Fourwing saltbush (Atriplex canescens)
1 Ibs/acre Cliffrose (Cowania mexicana")
2 Ibs/acre Alkalai sacaton ("SporoboluT airoides
8. After seeding is complete the stockpiled trees will be scattered <
evenly over the disturbed areas and walked down with a dozer. The i|
access will be blocked to prevent future use. ••- I1,/
i1'
9. Water bars will be constructed as directed by BLH to control erosion! '
10. The dirt contractor will be furnished with a copy of these stipulatii
and a copy of the operator's Surface Use Plan prior to any work. ^
H
Production |j.
1. The operator will notify the San Juan Resource Area BIM Office in \\
Monticello, Utah (phone (801) 587-2201) if the well is determined
to be a commercial producer.
2. The reserve pit and that portion of the location and access road
not needed for production or production facilities shall be reclaimec
in the methods described in the rehabilitation section. Enough
topsoil should be retained to reclaim the remainder of the location
as^a future date. The remaining stockpile of topsoil shall be
seeded in place using the prescribed seeding mixture.
3. All above-ground production facilities will be painted a neutral
color to be approved by the BLM.
4. The dirt contractor will be furnished with a copy of these stipulatio
and a copy of the operator's Surface Use Plan prior to any work.
5. The access shall be upgraded to the following specifications:
To be determined if production is obtained.
C-1074
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C-1075
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C-1076
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Sampling Report
Investigation of Wexpro Company's Island Unit No. 27
Uintah County, Utah
July 2, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005), with the changes noted below. This
site was originally planned to be selected randomly from a list
of active Uinta Basin drill sites developed by the Utah
Department of Natural Resources - Oil, Gas, and Mining Division
at the request of EPA. The list was to be developed just prior
to July 2, 1986, the scheduled sampling date. The short time
frame was deemed necessary because of the uncertain progress of
drilling in this area. It would be impossible to plan the
sampling of an appropriate drill site more than a day or two in
advance. Randomization and site selection were to take place a
few days before sampling.
On June 20, 1986, the Department of Natural Resources notified
the EPA contractor that it was unable to locate more than one
drill site at or near completion for sampling. The single
available appropriate site is considered a random sample because
it was the only site known in the desired basin during the
necessary time frame. No bias was introduced into the selection
of this site. It was selected on the basis of availability. No
information was available to indicate this site was an
appropriate site for sampling.
The site was identified as Wexpro's The Island Unit No. 27 in the
Uinta Basin. No problems were encountered arranging for sampling
the Wexpro drill site on July 2, 1986.
Site Location
Wexpro Company's Island Unit No. 27 is located 15 miles southwest
of Ouray, Utah. Figure 1 is a map indicating the drilling site.
The site is operated by Wexpro Company.- whose mailing address and
telephone number are:
PO Box 458
Rock Springs, WY 82902
Contact Name: Lee Martin
307-382-9791
C-1077
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e * V Crossing * \'>-^ - Cx^J'.J-ry_/S - — --=-"1"- "7 l
SITE LOCATION
£•%
'^:\j^^ y
" ^
Figure 1. Location of Wexpro Island Unit #27, Uintah
County, Utah
C-1078
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Attendees
Sampling of Wexpro Company's Island Unit No. 27 was performed by
CENTEC Corporation personnel on July 2, 1986. The following is a
list of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representatives:
Operator Representative:
American Petroleum
Institute Representatives:
Bruce Hoskins, Team Leader
Andy Procko, Engineering
Manager, Acting Technician
Carol Kubly, Utah Dept. of
Natural Resources; Oil, Gas &
Mining Division
Dan Jarvis, Utah Dept. of
Natural Resources; Oil, Gas &
Mining Division
No representative on location
Maurice Jones, Contracted
Observer
Bob Zahray, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
Site Description
Wexpro Company's Island Unit No. 27 is located within the Uinta
Basin in an area of rural flatland. The nearest surface water is
less than 1/2-mile away. There are no drinking water wells
within a 1/2-mile radius of the site. The soil in this area is
sand and clay. The climate at this site is net evaporation.
This site was a developmental gas drilling site. The well was
completed on June 28, 1986 at a depth of 6,600 feet. Drilling
was accomplished with gel chemical water based mud. No biocides
were used in drilling. Fracturing was used as the completion
process.
Figure 2 is a schematic diagram of the drilling site. One pit
was constructed for the site. The pit dimensions were 122 feet
long and 99 feet wide. The pit was constructed to be used as a
reserve pit. There were no special pit construction
requirements. Leak detection was not required. The pit was
lined with a plastic liner of 2 mil thickness. The liner was not
UV or puncture resistant. The pit received drilling muds, fresh
water, completion fluids, and trash. The fluids were piped into
the pit from drilling operations. The pit area was fenced. The
pit construction was below grade. The sludge depth in the pit
was 1/2 foot. The liquid level in the pit was 5 feet. Photo 1
(Attachment A) shows the well head at the site. Photo 2 shows
the well head and the heater treater. Photo 3 shows the entire
C-1079
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\MELL
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PIT
1
Figure 2. Schematic Diagram of Wexpro Company's Island Unit 27
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site (well head, heater treater, and reserve pit). Photo 4 is a
closeup of the reserve pit.
Disposal Practices
At the conclusion of drilling, all remaining drilling fluids were
placed in the reserve pit. There was no testing of pit contents,
nor was there treatment of pit contents. The pit fluids were not
removed for final disposition. The liquid was evaporated. The
dried pit solids were buried. The pit site was reclaimed by the
addition of stockpiled topsoil and reseeding.
Permits
The well was drilled on Federal land. The permit for this
facility is No. 43-047-31703 issued by the Bureau of Land
Management on March 18, 1986. A copy of the permit and the
drilling program are included in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Wexpro Company's Island Unit No. 27
consisted of one reserve pit supernatant sample and one pit
sludge sample. Figure 2 shows the sampled pit and the location
of the sample points. Four quadrants were established for
supernatant and sludge sampling. Sample points were accessed by
boat. There were no discrepancies between the actual and
measured sample points.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants and to locate the center of each
quadrant. The supernatant was collected from the boat with a
liquid sampling thief. For sludge sampling, the coring tube was
not used due to concern that the pit liner might be punctured.
The sludge was sampled from the boat with a Ponar dredge.
The pit supernatant was tested onsite for pH after sampling was
completed. Test results gave a pH value of 6. Due to time and
travel constraints, the collected samples were held overnight in
refrigeration prior to shipment.
C-1081
-------
C-1082
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1083
-------
C-1084
-------
ISLAND UNIT WELL°?7
TIOSR206
UINTAH COUNTY. UTAH
OPERATOR WtXPRO CO.
Photo 1. Wei I head
Photo 2. Well head and heater treater
C-1085
-------
WS^Wa^^^^?^ j9^ I .-v ?':?;';?:;v v; -"'
f^raHSffTOt'ft'^lfi&'^^'^'-iV'w.'f>^>i/>-v,..¥"'' . , . •• •
--\.'^ "Xh^ ^
Photo 3. Reserve pit, well head, and heater treater
Photo 4. Reserve pit
C-1086
-------
ATTACHMENT B: PERMITS
C-1087
-------
C-1088
-------
CORRECTED 7-9-86:
'Form, approved.
•ESTJS. ' UNl:( ESTATES V SUBMIT IN DCTUC<£
,&• ." DEPARTMENT OF: THE INTERIOR -j. e^^-
..,'•' •-.;. -: BUREAU. OF LAND. MANAGEMENT:" -¥-••*-: •/•_•'
WELL. COMPLETION OR RECOMPLETIOrjCJfpjCJJ
VTTPB Or COMPLETION:
•iw ra WORK (—1 I»RKP~ r— i
WM.L U3 «»•« LJ ex LJ
"l IA|I I OP OPERATOR
Wexpro Company
WE'LL LS- •'' O*T Llj\I i**^ -r-
n r« r—| HIPP. rnT J (J L
..^s ILJ B.-«r. i j o(t>»>/ r:.
sWm\
• w-M ftAC JL MlUlkjrc
TAWMIB** OP OPERATOR *••». vrfi-iw t* irniiiiivrf
P. 0. Box 458, Rock Springs, Wyoming 82902
It tap prod. Interval reported below
At total depth
19. DAT! SrUDDED 1«. DATE T.D. REACHED
S-1-R6 5-13-86
St TOTAL DEPTH. MD * TYO 21. PLUO, IAOC 1
. 6600 6497?
845' FNL
14. PERMIT NO.
IT. DATE COUPL. (Rtadf to prod.) |
7-2-86 . (
J_ MD » TTD 22. IP M( I.TIPI.C COM7(
HOW »AKT«
14. raODfCINO l! WBU. COKCO
No
CASING RECORD (Kffort all itringt tel In well)
CASINO sttt
9-5/8
' 5
M.
•Ill
'
WEIGHT. U./PT.
36
18
DEPTH «ET (MO)
314.09
6599.32
HOLE SIZE
12-1/4
"7-7/8
CCMENT1NC RECORD
310 sacks Class H
640 sacks High Fill
260 sacks 50-50 Pozmix
— LINER RECORD
TOP (MD)
•OTTOM (MO)
SACK* CCME.VT*
«. mrouTiOH IECOED (;«l. 1.0 1 511
OIL RRL. «A* MCP. WATCR RRl
0 533 1 75
«
-------
Form 3160-3
(November 1983)
(form.rlf 9-331C)
UNITED STATES
SUBMIT IN TRIPLICATE*
(Other Instructions on
rererM ilde)
Form approved.
Budget Bureau No. I004-oi
Expires August 31, 1995
UtrAKiMtm ur mt micmun
BUREAU OF LAND MANAGEMENT
APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK
la. TTPI or woaK
DRILL B DEEPEN D PLUG BACK D
k. TTPC or WILL
OIL I— 1 OAI rrg SINOLB r— I MULTIPLI r— 1
WILL LJ WILL 0=3 ornta IONI LJ XONI LJ
2. NAME Or OPIBATOt
Wexpro Company
3. ADDBIBH or OPERATOR
P. 0. Box 458, Rock Springs, Wyoming 82902
4. LOCATION or WILL < Report location clrarlj and In accordance wlta aoj State requirements.*)
*'""""" NE NW 1800' FWL, 845' FNL
At propoard prod, aone
14. UIXTANCI IN MILES AND DIEECTION raOM NCAIEST TOWN OB POST OmCI*
Approximately 15 miles south and west of Ouray, Utah
10. DISTANCE rBOM PBOPtlBID*
LOCATION TO NIABIBT
PBOPEBTT OB LIABI LINE, IT. Q / c 1
(AIM to nearest drlf. unit line. If anr> O^O
1.1. DIBTAM-C raou raoroaio LOCATION*
oa APPLIED roa. ON THIS LEASE, pr. 2893 '
18. NO. or ACsaa IN LEASE
520 •• ^
19. PROPOSED DEPBH •' .
6>W
11. BlSYATiONs (Show wbetiMr OF. BT. GR. ate.) . \ e^* ^^"
GR 4784' /t 1 ^s^
»• «-•* MBIUNATION AND ISIUlTl
U»'D13768
«. W INDIAN, ALLOTTIB OB TIIII n~t
7. ONIT A01ICHIHT NAMI
Island
S. rABM OB LIASI NAMB
Unit
27
10. riILD AND POOL. OB WILDCAT "
liidud- • rV/f-7. Asrr.
11. BCC., T., B.. M., OB BLI.
AND SUBVIT OB ABBA
9-10S-20E
12. COUNTT OB PABISB 13. BTATI
Uintah Utah
17. NO. Or ACBEB ABSIONED
TO THIS WILL
NA
, 20. BOTABT OB CABLE TOOLS
Rotary
22. APPROI. DATS WOBE. WILL IT4I1
March 1, 1986
PROPOSED CASINC. ANffcKUENTINO PROGRAM
MIZC OP ROL.E
12-1/4
7-7/8
aizc or t-«mno
9-5/8
5-1/2
WEIGHT PER FOOT
36
17
• ITTINO DEPTH
300'
6,600'
UL'ANTITT OP CEMENT
IfiS Sprke Rponlar Type C.
with arldltlvps
50-50 Pozmix with additives
See attached drilling plan.
APPROVED BY THE STATS
OF UTAH DIVISION OF
. AND MIMING
FFB K' 1
DIV!Sirv
OIL. GAS i?.,
IN ABOVE IPACI Dtscitai P«OPOSID PIOOSAH : If propoul la to deepen or pluf back. jrlTe data on present productive aone and proposed n«w product!*
aonr. If proposal la to drill or daepen dlrectlonall?. ti»e pertinent data on subsurface locations and aeaaured and true Tsrtleal deptbi. 01" t>l°*°D
pr«Trat«r proirram. If anj.
.Drilling Superintendent
•2- ML.
(Thin upact (or Federal or State offlce
PtaiJIT No..
APPROVAL DATE .
Appaoviu ar _____^_^^^__
COXOITIOKB or ArpaovAL. ir ANT :
__ TITLE .
C-1090
*$•• Initructionr On R«v«n« Sid*
Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to.snv deosrtmeni or mvrnrv «' '•"
-------
LMMTAK CO. , UT^H
01 41
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01 C
41
41 60
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41 (0
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4-1 ,O V
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41 4J O.
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41 <0 *J
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r-l 4> -O
< O OJ
LOCATION PLAN
SCALE l"= 1000'
LEGEND
— — SURFACE OWNER BOUNDARY
' — • MINERAL LEASE BOUNDARY
t WELL LOCATION
NOTE- FOR SURFACE INFORMATION (ROADS, TOPO. DRAirOUi£,,-C*fc.)
«rr AnrA UAP -^'*-^' •'
SEE AREA MAP.
THIS IS TO CERTIFY THAT THE ABOVE PLAT WAS
OR. ACTUAL SLWVtT^ MADE pi ME OR UNDER MY SUPERStSIO
/SAME ARE TRUE^ANO CDRREtT Ttf THE BEST O
- 6389
THE; Mz
; - »«"«' r-^MH^wy&j&t—tn/a. \ ^ / s
x — XLARRY 6. BODYFELT, j^Tft-H REG. L.S. N« ^2>»J^7'£«*7rjr«V\»k OLA.R 0»<&&«.VAT10M
SURFACE OWNER'- UlNTAM < OORAX lUDIiVN RES. LA.VJOi
MINERAL LEASE: O )ll Iff, NO. ^- Xb O 62.
-------
f
DRILLING PLAN
Wexpro Company -
Island Unit Well No. 27
Uintah County, Utah
1 & 2. SURFACE FORMATION, ESTIMATED TOPS AND WATER, OIL, GAS OR
MINERAL BEARING FORMATIONS:
Uintah - Surface
Green River - 1,140'
Birds Nest Aquifer - 2,045'
Wasatch Tongue - 4,120', gas or oil
Green River Tongue - 4,465', gas or oil
Wasatch - 4,610', gas
Chapita Wells Zone - 5,430', objective, gas
Total Depth - 6,600'
All fresh water and prospectively valuable minerals (as
described by BLM at onsite) encountered during drilling, will
be recorded by depth and adequately protected. All oil and
gas shows will be tested to -determined commercial potential.
3. PRESSURE CONTROL EQUIPMENT: (See attached diagram)
Operator's minimum specifications for pressure control
equipment requires an 11-inch 3000 psi double gate
hydraulically operated blowout preventer and an 11-inch 3000
psi annular preventer. Ram-type preventers will be tested to
2000 psi and annular preventers will be tested to 1500 psi for
15 minutes using professional testing company. NOTE: The
surface casing will be pressure tested to a minimum of 1000
psi; or one psi per foot; or 70 percent of the internal yield
of the casing, whichever is applicable. BOP's will be checked
daily as to mechanical operating condition and will be tested
after each string of casing is run. All ram type preventers
will have hand wheels which will be operative at the time the
preventers are installed.
BOP systems will be consistent with API RP53. Pressure tests
will be conducted before drilling out from under casing
strings which have been set and cemented in place. Blowout
preventer controls will be installed prior to drilling the
surface casing plug and will remain in use until the well is
completed or abandoned. Preventers will be inspected and
operated at least daily to ensure good mechanical working
order, and this inspection will be recorded on the daily
drilling report. Preventers will be pressure tested before
drilling casing cement plugs.
The District Office will be notified, with sufficient lead
time, in order to have a BLM representative on location during
pressure testing.
C-1092
-------
4. CASING PROGRAM:
Footage Size Grade Wt. Condition Thread Cement
300 9-5/8 K-55 36 New 8 rd ST&C 165 sacks Regular Type G
with 3% calcium chloride
and 1/4-pound flocele/sack; -
cement will be brought to
surface.
6600 5-1/2 K-55 17 New 8 rd LT&C Cement top will be brought
1000 feet from surface
with 50-50 Pozmix with Q%
gel, 0.2% Halad-24, 10% salt,
5 pounds gilsonite/sack and
1/4-pound flocele/sack, plus
1000 feet 50-50 Pozmix with
2% gel, 0.6% Halad-24, 10%
salt and 1/4-pound flocele/sack
AUXILIARY EQUIPMENT:
a) Manually operated kelly cock
b) No floats at bit
c) Monitoring of mud system will be visual
d) Full opening floor valve-manually operated
The District Office will be notified, with sufficient lead
time, in order to have a BLM representative on location while
running all casing strings and cementing.
5. MUD PROGRAM: A gel chemical water base mud will be used from
surface casing to total depth.
Sufficient mud materials to maintain mud properties, control
lost circulation and to contain blowout will be available at
the wellsite.
No chromate additives will be used in the mud system on
Federal and Indian lands without prior BLM approval to ensure
adequate protection of fresh water aquifers.
6. LOGGING: DLL-SFL-GR from surface casing to total depth
BHC-Sonic with Caliper from surface casing to total
depth
CNL-FDC-GR over zones of interest
TESTING: None.
CORING: None.
Daily drilling and completion reports shall be submitted to
the Bureau of Land Management, Vernal, Utah on a weekly basis.
Whether the well is completed as a dry hole or as a producer,
"Well Completion and Recompletion Report and Log" (Form
3160-4) will be submitted not later than 30 days after
C-1093
-------
completion of the well or after completion of operations bei
performed, in accordance with 43 CFR 3164. Two copies of al
logs, core descriptions, core analyses, well-test data,
geologic summaries, sample description, and all other survey
or data obtained and compiled during the drilling, workover,
and/or completion operations, will be filed with Form 3160-^
Samples (cuttings, fluids, and/or gases) will be submitted
when requested by the authorized officer (AO).
7. ABNORMAL PRESSURE AND TEMPERATURE: No abnormal pressures ar
expected; a BHT of 150°F. and a BHP of 3370 psi are
anticipated.
8. ANTICIPATED STARTING DATE: March 1, 1986
DURATION OF OPERATION: 12 days drilling
No location will be constructed or moved, no well will be
plugged, and no drilling or workover equipment will be remov
from a well to be placed in a suspended status without prior
approval of the AO. If operations are to be suspended, prio
approval of the AO will be obtained and notification given
before resumption of operations.
The spud date will be reported orally to the AO within 48
hours after spudding. If the spudding occurs on a weekend 01
holiday, the report will be submitted on the following reguli
work day. The oral report will be followed up with a Sundry
Notice.
In accordance with Onshore Oil and Gas Order No. 1, this well
will be reported on Form 3160-6 "Monthly Report of
Operations", starting with the month in which operations
commence and continue each month until the well is physically
plugged and abandoned. This report will be filed with the
Vernal BLM District Office, 170 South 500 East, Vernal, Utah
84078.
Immediate Report: Spills, blowouts, fires, leaks, accidents,
or any other unusual occurrences shall be promptly reported i:
accordance with the requirements of NTL-3A or its revision.
If a replacement rig is contemplated for completion
operations, a "Sundry Notice" (Form 3160-5) to that effect
will be filed, for prior approval of the AO, and all
conditions of this approval plan are applicable during all
operations conducted with the replacement rig.
Should the well be successfully completed for production, the
AO will be notified when the well is placed in a producing
status. Such notification will be sent by telegram or other
written communication, not later than five days following the
date on which the well is placed on production.
C-1094
-------
Pursuant to NTL-2B, with the approval of the District
Engineer, produced water may be temporarily disposed of into
unlined pits for a period of up to 90 days. During the period
so authorized, an application for approval of the permanent
disposal method, along with the required water analysis and
other information, will be submitted to the District Engineer.
Pursuant to NTL-4A, lessees or operators are authorized to
vent/flare gas during initial well evaluation tests, not
exceeding a priod of 30 days or the production of 50 MMCF of
gas, whichever occurs first. An application will be filed
with the District Engineer and approval received, for any
venting/flaring of gas beyond the initial 30 day or authorized
test period.
A schematic facilities diagram as required by 43 CFR 3162.7-2,
3162.7-3, and 3162.7-4 shall be submitted to the appropriate
District Office within 30 days of installation or first
production, whichever occurs first. All site security
regulations as specified in 43 CFR 3162.7 shall be adhered to.
All product lines entering and leaving hydrocarbon storage
tanks will be effectively sealed in accordance with 43 CFR
3162.7-4.
A first production conference will be scheduled within 15 days
after receipt of the first production notice.
No well abandonment operations will be commenced without the
prior approval of the AO. In the case of newly drilled dry
holes or failures, and in emergency situations, oral approval
will be obtained from the SO. A "Subsequent Report of
Abandonment" Form 3160-5, will be filed with the AO within 30
days following completion of the well for abandonment. This
report will indicate where plugs were placed and the current
status of surface restoration. Final abandonment will not be
approved until the surface reclamation work required by the
approved APD or approved abandonment notice has been completed
to the satisfaction of the AO or his representative, or the
appropriate Surface Managing Agency.
Pursuant to Onshore Oil and Gas Order No. 1, lessees and
operators have the responsibility to see that their
exploration, development, production, and construction
operations are conducted in a manner which conforms with
applicable Federal laws and regulations and with State and
local laws and regulations to the extent that such State and
local laws are applicable to operations on Federal or Indian
lands.
C-1095
-------
CELSIUS/WEXPRO
3000 psi BLOWOUT PREVENTION EQUIPMENT
n
i
o
vo
-------
STANDARD STACK REQUIREMENTS
N2
— —
1
I
3
4
5
6
7"
8
-.9
10
11
12
13
14
15
16
••^-••™,
17
18
•^•BHH
— —
ITEM
(Rotating Heac
Drilling Nipple when air dri]
Flowline
(eliminated for
Fill up Line air drilling)
Annular Preventer
Two Single or One dual Hydril
oner rams.
Drilling spool with 3" and 2"
outlets
As .Alternate to C6) Run i Kill
and Cnoke lines from outlets
in this ram
Gate Valve
Valve-hydraulically operated
(Cate)
Choke Line
Gate Valves
Check Valve
Kill Line
Gate Valve
Kill Line to Pumps
Casing Head
Valve Gate
Plug
Compound Pressure Cage
Wear Bushing
— •
NOMINAL
line)
2"
3"
2"
2"
ID
3-1/8
3-1/8
2-1/16
2-1/16
2-1/16
1-13/16
TYPE
Hydril
Cameron
Shaffer
y-pfis-
F . EWS ,
R P
Forged
FURNISHED BY
OPER.
•
CONTR.
i
;
01097
-------
STANDARD CHOKE AND KILL REQUIREMENTS
N?
19.
20
21
22
23
24
25
26
27
ITEM
Cross 3" X 3"
3" X 2"
Gate Valve
Compound Pressure Gage
Gate Valves
Choke Cam H-2 or
equilivent
Gate Valves
Line
Line
Line
NOMINAL
3"
3"
3"
3"
10
1-13/16
3-1/8
2"
3-1/8"
TYPE
HJRNISHED BY
OPER.
-
CONTR.
01098
-------
WEST VIRGINIA
C-1099
-------
C-1 100
-------
Sampling Report
Investigation of Scott Oil Company's
Garvin Lease Well No. S-614
Jane Lew, West Virginia
August 19, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Appalachian Basin drill sites developed by the West
Virginia Department of Natural Resources Division of Oil and Gas,
at the request of EPA. The list was transmitted via telephone to
the EPA contractor on August 11, 1986. Randomization and
selection took place during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number,/API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Division of Oil and Gas listed the possible sample sites by
permit number at their preference, as shown below. The list
consisted of twelve drilling sites in the Appalachian Basin:
1. 17-3489
2. 17-3458
3. 17-3483
4. 17-3504
5. 21-4429
6. 21-1774
7. 39-4329
8. 39-4330
9. 39-4331
10. 41-3712
11. 41-3728
12. 41-3730
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 1 on the above list
(permit no. 17-3489). No. 10 on the above list (permit
no. 41-3712) was selected as a back-up site in the event the
primary site was inaccessible or inappropriate.
C-1101
-------
Further inquiry identified the primary sample site as an
inappropriate site. The site had been drilled, but fracturing
would not be completed by the scheduled date for sampling. Thus,
the back-up site was investigated.
The back-up site was identified as Scott Oil Company's Garvin
Lease Well No. S-614, at Jane Lew, West Virginia. No problems
were encountered in arranging sampling for August 19, 1986.
A second back-up site was randomly selected (permit
no. 17-3504). The site was identified as Consolidated Natural
Gas Operating Company's drill site in Doddridge County. The
back-up site was not required.
Site Location
The Garvin Lease Well No. S-614 is located approximately one-
tenth of a mile east of the intersection of Highway 79 and County
Road 8 in Jane Lew, West Virginia. Figure 1 is a map indicating
the drilling site. The full name and mailing address for Scott
Oil is:
Scott Oil Company
P.O. Box 112
Salem, WV 26426
Main Office Contact:
Phone;
John T. Haskins
Vice President
304-623-9600
Attendees
Sampling at the Exxon site was performed by CENTEC Corporation
personnel on August 19, 1986. Following is a list of people
present at the time of sampling:
CENTEC Corp. (Sample Team):
EPA Representatives:
State Representatives:
Jim Kourmadas, Technician
Jamie Mclntyre, Team Leader
Susan de Nagy, Office of Water,
Project Officer
Truett DeGeare, Chief, Special
Wastes Branch
Dan Derkics, Chief, Large
Volumes Section
Ted Streit, Deputy Director,
Division of Oil and Gas
John Johnston, Director,
Division of Oil and Gas
Roger Steward, Chief Inspector,
Division of Oil and Gas
Steve Casey, Inspector,
Division of Oil and Gas
Mike Underwood, Inspector,
Division of Oil and Gas
C-1102
-------
HARRISON
SITE LOCATION.
Figure 1. Location of Scott Oil Company's Garvin Lease
Well #S-614, Jane Lew, West Virginia
C-1103
-------
Operator Representative:
American Petroleum
Institute Representatives:
Other Observers:
John Haskins, Vice President
George Holliday, Contracted
Observer
Alan Willson, Contracted Sample
Team Member
Kyle Hodges, Contracted Sample
Team Member
Rex Bruford (and wife).
Executive Secretary
of the West Va. Oil and
Natural Gas Association
Richard Cook, Consolidated Gas
Joe Petty, Union Oil
Dave Flannery, Attorney,
Robinson and McElwee
Fred Kolb, Kolb Enterprises
Site Description
The Garvin Lease site is located in a rural, mountainous area.
The climate at this site location is net precipitation. The soil
is described as clay. The site is located over the Benson
formation of the Appalachian basin. Figure 2 is a survey of the
exact location of the hole.
The depth to the groundwater in the area is over 100 feet. The
nearest surface water is a stream located less than 1/2 mile from
the site. There are two drinking water wells located within a
1/4-mile radius of the site, and two drinking water wells between
1/4 and 1/2 mile from the site.
At the time of sampling, the site consisted of one gas well, one
completion fluids tank, and one reserve pit. The well had been
drilled but was not in production at the time of sampling. The
drill rig had been removed from the site. Figure 3 is an
approximate schematic diagram of the site, indicating the
directions in which photos were taken (Attachment A).
This site was a developmental oil drilling site. The well was
completed at 5,867 feet. Drilling began on July 26, 1986 and the
well was completed August 8, 1986.
Drilling was accomplished using air rotary drilling. The Benson
formation was fractured in the well with fresh water stored
onsite in a tank. The tank was empty at the time of sampling,
and is shown in Photo 5 to the far right.
One unlined pit was constructed onsite to provide temporary
storage of drill cuttings, fresh water, and produced brine. The
operator stated that there was 80 percent fresh water to 20
C-1104
-------
H2Ttf-
IAT1TUDE
WAMNU
104" TO IO*MCKMV
, M* TO B'WCIKMV
#'•
CTM Ul) •
•&OUVIU4 I
?* MM'
•tie
MMIIB .
'
MMIT)
•
MAXON
Htt H. It TH SI
ciMKtiutg, my taa
HtOH€» 304 - «J -ff/«
(*) DENOTES LOCATION OF WELL ON UNITED STATES TOPOGRAPHIC MAPS
MAXON
RLE NO
DRAWING NO.
SCALE 1
MINIMUM DEGREE OF
ACCURACY I l» tOO
PROVEN SOURCE OF
ELEVATION TO»OF KNOi MCdft.
OF LOCATION tLtV. • BOB'
I THE UNDERSIGNED. HEREBY CERTIFY THAT
THIS PLAT IS CORRECT TO THE BEST OF MY
KNOWLEDGE AND BELIEF AND SHOWS ALL THE
INFORMATION REQUIRED BY LAW AND THE REGU-
LATIONS ISSUED AND-f RESCRIBED BITHf DEPART-
MENT OF ENERGY/ rr~~f~ f) / V
SlBNEm /I IS+~S^,# MF«V
(SIGNED).
R.P.E_
_LS._
PHEM 0. COiH
STATE OF WEST VIRGINIA
OIPARTMENT OF ENUQV
OIL AND GAS DIVISION
DATE_
MAY 06
OPERATOR'S WELL NO. .
API WELL NO. •AOVIN HO. I
47 _ 041 _ 37 s ?,
WELL TYPE OIL__GASJLLIQUID INJECTKJN__WASTE DISPOSAI STATE COUNTY PERMIT
(IF -GAS.T PRODUCTIONJLSTORAGE DEEP SHALLOWjL.
LOCATION:ELEVATION__!£Sll__WATERSHED Jtllt HUM
DISTRICT.
MACKM
QUADRANGLE WEtTOM T
SURFACE OWNER SvtvfA L. •OOFBEY
.COUNTY.
HWIi
OIL t GAS ROYALTY OWNER «IO*g BAR VIM
LEASE NO.
I»S9
.LEASE ACREAGE.
.ACREAGE.
IB
IB
PROPOSED WORK:DR1UJLCONVERT_DRILL DEEPER REDRIU__FRACTURE OR
mMULATE__PLUQ OFF OLD FORMATION PERFORATE NEW
FORMATION__0THER PHYSICAL CHANGE IN WELL (SPECIFY) __
PLUG AND ABANDOH__CLEAN OUT AND REPLUQ__
AARGET maum™ ILK/JO«OM/»AYAW gsriuATgn DEPTH__»lfi2—
JwELLQPCPATna tCOTT OB. COMFAMY DESIGNATED AGENT.
ADDRESS P.O. JOX n» ADDRESS
OABRtL WRUHT
P.O. IPX lit
tALCM.WV t»4I«
«AHM. WV t«4t>
Figure 2. Survey of Well Location
(size of copy has been reduced)
C-1105
-------
%
Figure 3. Schematic Diagram of Drilling Site
C-1106
-------
percent brine in the pit. The pit contents were piped from the
drilling operation. The pit was in use between July 26 and
August 8, 1986.
The pit was constructed both above and below grade due to an
upward slope from southwest to northeast. Photo 1 shows the
difference between the southwest and northeast sides of the pit.
The pit had been treated prior to sampling. Treatment included
pH adjustment with lime (to a pH of 11.3), aeration and mixing of
the entire pit contents. Treatments occurred after drilling and
after completion. Field and laboratory tests were performed on
the pit contents before and after treatment, and included the
following analyses; pH, dissolved oxygen, chloride, iron,
manganese, specific conductivity, total suspended solids, and
total organic carbon. Figure 4 is a copy of a laboratory report
on a sample taken from the pit on August 14, 1986, 5 days before
the CENTEC team sampled the pit.
At the time of sampling, the average depth of the fluid in the
pit was 1-1/2 feet. The average depth of the sludge was 4 feet.
The liquid appeared clear with a greenish tint, shown in Photo
11, and the sludge had the consistency of pudding.
Disposal Practices
The liquid in the pit was to be land applied, although the
specific land destination was not identified by the operator.
The solids would remain in the pit, and the pit would be
backfilled. The area would be restored to nearly its original
state, including revegetation.
Permits
Copies of the drilling permit and the Construction and
Reclamation Plan submitted by Scott Oil Company for Garvin Lease
Well No. S-614 are located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Garvin Lease site, the samples were defined as the
supernatant and solid contents of the waste material in the
reserve pit. Figure 4 indicates the location of the sample
points from which the pit samples were composited.
C-1107
-------
RELIANCE LABORATORIES, INC. ORIGINAL DOCUMENT
304/842-5285
WATER • WASTE WATER • SOILS • COAL • HAZARDOUS WASTE • AIR • ORE
3CDTT OIL COMPANY
7>. 0. Box 112
Salem. WV 26426
August 14. i=S6
Sample I.D.: Garvin
Lab. Number: W-26664-86
P. 0. BOX 625
BENEDUM INDUSTRIAL PARK
BRIDGEPORT, WV 26330
pH
SM 423*
Iron
3M 315 A, 315 B*
Manganese
SM 319 A, 319 B*
Chloride
SM 407 A, 407 C*
Specific Conductivity
SM 205*
Total Suspended Solids
3M 209 C*
Total Settleaole Solids
SM 209 F*
Total Organic Carbon
SM 505*
11.71 (Std. Units)
1.19 mg/1
0.20 mg/1
I960 .ng/1
5OOO unhos/cm
78
-------
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 3, and to locate the
center of each quadrant. The measured points were marked by
placing stakes along the sides of the pit to facilitate locating
sample points.
The sample points were accessed by boat. The boat was pulled to
the measured sample points via three ropes, as shown in Photos 7
through 10. Observers volunteered to assist with the ropes.
The first sample to be collected was the liquid composite.
Photo 9 shows the sample team taking a thief sample. Care was
taken not to allow silt from the sludge layer under the liquid to
enter the thief. The liquid from each sample point was
composited in a 5-gallon carboy.
The reserve pit was then sampled for sludge. The coring device
was used to sample the sludge with a 5-foot extension rod
attached. The device sank into the sludge such that 1 foot of
the rod remained above the liquid surface. Since the total
length of the rod and coring device is 6 feet, 8 inches and
assuming the average liquid depth to be 1-1/2 feet, the depth of
the sludge was determined to be 4 feet, 2 inches. The coring
device was nearly full each time it was retrieved from the
sludge, suggesting that the pit contents were approximately
homogenous. Four 1-quart core samples were taken at each
quadrant, and were composited in a steel bucket. The total
volume was approximately 4 gallons.
Tests for the pH and free chlorine content of the pit samples
were conducted onsite after sampling was completed. The pH of
both pit samples was 9. The free chlorine content of the liquid
was less than 0.2 ppm (the lowest detectable level).
C-1109
-------
C-1110
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1 1 1 1
-------
C-1112
-------
Photo 2. Drill pad (left) and reserve pit (right)
Photo 1. Southeasterly view of reserve
pit
-------
O
I
Photo 3. Northwesterly view of reserve
... L* -. ulAii V \»
Northerly view across reserve pit
-------
o
I
Photo 5. Northwesterly view across drI I \ pad
(well head just left of center)
Photo 6. Southerly view of drill pad
;Mirf^ ^^-.^^^Sl^^^SS^
Photo 7. Sampling reserve pit
Photo 8. Sampl ing reserve pit
-------
KSfflSiLw, A..^.!,.--.-^ *¥•— -Av^-^:-rr
Ebrffcs^-
Photo 9. Liquid sampling with thief
Photo 10. Liquid sampling with thief
O
I
cr>
-------
ATTACHMENT B: PERMITS
C-1117
-------
C-1118
-------
. ..'?
fum.«3 "^ -iST,^./ i • < .;.••-•.- ' /ST* ;
^^^.':^^m
;,:A;^H^M% ••-^^- «
• >:£<""' tii-ii-i*/' • ";STATEO?^
- ""f" ~? '• DEPARTMENT OF ENEROV,
I) Date:.
19.
-.- 2) Operator's '•-.'•-,»•"•:.. -••-•-"•• -. :-
,:/.'; well NO. j S.61/| Qoorgo Carvln -fT "'
o. 47 r>/ii — •a'?-! 9
State
County
Permit :
STATE
DEPARTMENT OF ENEROT, 6lL AND'GAS DIVISIPN
' . .APPLICATION FOR A WELL WORK PERMIT
4) WEU.TYPE: A Oil _ _/ G«J
• B (If "Gas", Production
5) LOCATION: Elevation:
District: _
/ Underground storage
Shallow
Watershed: - JeSSTfl Run
-.County
;!6) WELL OPERATOR SCOtt Oil CO.
Address P '__ Q. BOX 1 ** ^
Salem. W\
3PJ4.11 K '^DESIGNATED AGENT .
•' ''^Address P. 0.
.Quadrangle: WflCtQn 7.5 ^
. WV
I) .OIL & GAS INSPECTOR TO BE NOTIFIED
• Stephen Case
9) DRILLING CONTRACTOR:
• i Name :-^ r--.
;:;,Addre« ; .Route 2
Jane Lew. WV
10)/PROPOSED WELL WORK: . "HII ••' X / DHU
- jil: V- Address
_/, Redrill
ii • •,. 'j " • - • ',>•-•..• • • i • • ' r : i
•"^^-v-v.-^-.''.' '•;. i,' -'"••• Plug (iff .old formation • ••/. .Perforate nevij .tonnatii
. .-:'.. •.-'V'., . .':;.;.'.••.,.. Other physical change in well (specify) •'•
• ii) 'OEOt/y?ic'A|:TApr.pTFnpvtATin^a^*^' Elk/Bsnspn/Bayard i\>A.v-v
• 14) . Approximate coal seam depths:
15) CASING AND TUBING PR6GRAM
__Jscoal bein'g^iined.ih the affia7"~Yes_
CASING 0«
TUBING TYre
. Coodww ' •
• FMlinur'
Col
lilamedliu '
nvductioB *•
::Tita,"~ -^~:
: U«n
- 1 . '•
•. ;> • "
- -,.^^. -.„•...:
Sa
11 3/
8 5/8
4-1/2
•— •—
••'.'•VftE
4-^^_
.-.-. ; *
' sita
^
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' .•-*;•' •
"•'•-. " . '•
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•"-vf—r
•tts • ?•
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nATIONi
krtflll
KTft.
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. 1
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* •
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TT-
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-tlfiy-'
. FOOT ACE !•
-30'
' -• . •• •
'- -• ' -. •• ' ' •
^-r-r,-,r-c:.-rr^r
-.••—--^..-•ii^"
•a; 10 'a3H.t;!J-
(TE"'vfe';-r •.
-. '«V •:.- ' '
; '*&l' •-••'^:
. --*^\ •-••
-650
rrr-54001— r
,v_ii --^..~
^..i-J ^XCi-'ftS.
-.. .;•:.
ftEMEMFIUAT
f // OR SACKS • .
•lY (CiMcfml
vV. '• '•"•' •- "•
•>\-;', ,.-•••: .
-.v--- • •_
to surface •
300 -sks —
— - — —- — •-•
7 »v '.-:;i.-:..
. T ' '
.-._
' PACKERS r . . x
Kindj • "'
-Dn>tM KI •: --! J
-— i----..^ , . -«_.
P^rforwioiu:' '7 • ^<-'{ ? .'..•!•
1 Top . ' touan - '
.
'**
Vvf
-1 T£
' . . -F,
-/.'&
.'•' -1
: • ; • .- '- • • .:••••
Permit number - - " VTXA *K x
OFFICE USE ONLY
. DRILLING PERMIT
-
*•.'
.May, 30
\
. ^. ^
j .
.1
. 1986.:':.
/•_ --.- -;. r • ; ;'.->: ••' • • . --- •/• :;; '; : • -' Date - v. ,-,V
Thii permit covering ,the well operator and well location shown below is evidence of permission granted to drill in accordance with the pertinent legal re-'
Wirements subject to the conditions contained herein and on the reverse hereof.,vo,jfjcl,j0n must b« gi* p»rmlll«J «ork. '« addition, the well operator or his contractor shall notify the proper
district oil and gas inspector 24 hours before actual permitted work has commenced.) , __
The permitted work Is'as described in the Notice and Application, plat/and reclamation plan, subject to any modifications and conditions'specified on the V
r"heKof< «ay:-30. 1988 V > ,- -.
™n« expires • • ' • ' • unl«t well work is commenced prior to that date and prosecuted with due diligence.
^ NOTE:' Keep one copy of this permit posted at the drilling location.
Permit
.'he reverse ildeoJ the APr^lCANT'9'TOPY fpr inslructioiu to lh< »ril optralor. .'..-. ^ .->.'•:;
-^
-------
WW-9
DAIS'
Ml
MAY 13
; of EHEEGY
3X1 sni . i^y^fiTH]) AGQ5T
Teladtone
— ^evegetatdxaa to be t.vu i JpfT .out by
plan has be«?n reviewed by
ar^i't"inr'g
a part of this plan; • T*S"j ^
ACCESS PQAD
/-^—Tv»yyey\.
.^^
• • -.'Structure
Spadi5g_;
ICCKTICH
Z?/*V/JV«A»
(i)
Material
Page Eef. Manual_
Page'Eef. Manual
Structbre
(2)
Material Hay o^'" j^-i
Page Fe£.
Structure_
Material
(3)
Page Eef. Manual
Page Bef.
All structures should be inspected regularly and repaired if necessary. All
cpmercial timber is to be cut and stacked and all brush and small timber to be
cut and removed from the site before dirt work begins.
|M1 ri
Treatment ftrea I
or correct to pH 6, f
Fertilizer
Mulch
,
'
Treatment.
133s
or corxect to pH
'
_
(10-20-20 or equivalent) »',
' ^
,
ivi : Mulch Ab/
.
(10-20-20
Seed* /g">/
^' -"-'zlTTcns/aere
-iSS' Ibs/aere
tjtut, • '•&3S' Ibs/acre
'
e KiAtL "^?6 "Ibs/acre
Ibs/acre
^ ' ' ^
*JnocaZate all legumes such as vetch, trefoil and clovers with the proper bacterium.
Inoculate uith 3X xecoianended amount.. .. ;. /
^r pr.-rcor >wv
seedling for sns frcvinf «
Attccn sepcrsra sr.ccrs is
necessary for
£(J. t/A
fSCSS SO.
C-1«20
-------
A1TAC3 OR
INVOLVED
']<
1 SECTION
OF
Wel Site
Access Bead
rsc
HEEL SHE PLKN
: ketch to include well location, existing access road, roads to te constructed, wellsite
•drilling pits and necessary structures numbered or lettered to correspond with the fir*-1:
of this plan. Include, all natural drainage.
-
LEGEND
--•' ' '^ r
Qdsting fence -_.. ;* . X • ' '•
1 Planned fence ' S /',.L • ..- ,"
Stream **\,'""s^-**-'^""*.«'™\_ >~
Open ditch ...» ,....> , ...j>
;•,' i .
_Soring _O^, _^-i-T-ii-""r"' ^ — '"'-^ —
Wet ttxjt \y~ £ '.. ..
••'• '• Building El-^/-^' -V" "''
.Drainpipe1 0 — fr— O : : .>•
Waterway <^t'=^» -=« -=r
C-1121
-------
C-1122
-------
WYOMING
C-1123
-------
C-1124
-------
Sampling Report
Investigation of Diamond Shamrock
Exploration Company's Myers State Well No. 41-16
Gillette, Wyoming
July 13, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). Although EPA worked with the
Department of Environmental Quality and the Oil and Gas
Conservation Commission to identify appropriate drill sites prior
to the public meeting scheduled for July 11, 1986, no list of
sites was forthcoming.
The list of possible sample sites was presented to EPA by the Oil
and Gas Conservation Commission at a public meeting held in
Casper, Wyoming, on July 11, 1986. Attendees included
representatives from EPA, Wyoming Department of Environmental
Quality, Wyoming Oil and Gas Conservation Commission, oil and gas
companies, and the public. EPA requested identification of a
number of drill sites at or very near completion during July
13-14, 1986, in the Powder River Basin for site selection
purposes. The Wyoming Oil and Gas Commission identified the only
site: Cities Service Oil and Gas Corporation H.D.U. Well
No. 5346. Diamond Shamrock Exploration Company volunteered a
second possible site, their Myers State Well No. 41-16, near
Gillette, Wyoming. Since no other sites could be identified by
meeting attendees, EPA conducted a coin toss to determine which
site would be selected.
Cities Service Oil and Gas Corporation H.D.U. Well No. 5346 was
selected as the primary site. Diamond Shamrock Exploration
Company's Myers State Well No. 41-16 was selected as the back-up
site in case the primary site proved inaccessible or
inappropriate.
The Department of Environmental Quality and the EPA conducted a
presurvey of the primary site on July 12, 1986. Although the
reserve pit was intact, the site was disqualified as an invalid
drill site. Well No. 5346 had been completed approximately 4
months earlier. The site was not considered newly completed.
No problems were encountered arranging for sampling to be
conducted at the back-up site (Diamond Shamrock Exploration
Company's Myers State Well No. 41-16) on July 13, 1986.
C-1125
-------
Site Location
Myers State Well No. 41-16 is located approximately 4 miles south
of Gillette, Wyoming. Figure 1 is a map indicating the well
site.
The site is operated by Diamond Shamrock Exploration Co., whose
mailing address and telephone number are:
PO Box 2530
Miles, WY 82644
307-266-1882
Contact Name: Odell Williams
Attendees
Sampling of Myers State Well No. 41-16 was performed by CENTEC
Corporation personnel on July 13, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team):
EPA Representative:
State Representatives:
Operator Representative:
Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
Susan de Nagy, Office of Water,
Project Officer
E. J. Fanning, WY Dept. of
Environmental Quality
Tom McCall, WY Oil & Gas
Conservation Commission
Odell Williams, Drilling
Foreman
American Petroleum
Institute Representatives: Maurice Jones, Contracted
Observer
David Havis, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
Earl Kinsley, Contracted Sample
Team Member
Site Description
Myers State Well No. 41-16 is located in the Powder River Basin,
in an area characterized as rural foothills. The depth to
groundwater is unknown, and the nearest surface water is over 2
miles away. There are no drinking water wells within a 1-mile
radius of the site. The soil in this area is loam. The climate
at this site is net evaporation.
C-1126
-------
!"99
"94
Figure 1. Location of Myers State Well #41-16, Gillette,
Wyoming
C-1 127
-------
This site was an exploratory oil drilling site. The well began
drilling on June 24, 1986. On the day of sampling, the well was
at the completion depth of 10,571 feet. Drilling was
accomplished with freshwater muds and low-solid, non-dispersed
muds. The low-solid, non-dispersed muds consisted of gel, soda
ash, Biotrol, CFLA, caustic, ASP-700, salt gel, salo dust, cedar,
driscose, and starch paper. Chloride content of the mud on the
day prior to sampling was 33,000 ppm; pH was 9; hardness was 160
ppm. Drilling was performed by Cyclone Drilling.
Figure 2 is a schematic diagram of the drilling site. One pit (a
reserve pit) was constructed for the site. The pit was
constructed below grade. The pit was unlined and had no special
preparation prior to use. The total cost of pit construction was
$6,000. The pit was square in shape, with each side measuring 84
feet. The pit received drilling muds, deck drainage, fresh
water, and waste diesel oil. The pit area was fenced. Diversion
ditches were required. Photos 1-3 (in Attachment A) show the
reserve pit. Photos 4 and 5 show the pit and the drilling rig.
Photo 6 shows the mud recirculator on the rig.
A mud recirculation system was used at this site. The total
system volume on the sampling day was 1,235 bbl mud recirculated;
this consisted of 885 bbl calculated hole volume and 350 bbl in
steel mud tanks. The fluids were piped from drilling operations
into the pit. The supernatant depth in the reserve pit was 2-3
feet. The total volume of drilling fluids in the reserve pit was
estimated at 15,000 bbl.
A total of 300 bbl of diesel oil was stored in tanks at this
facility. Approximately 10-20 gallons of waste engine oil was
generated. The waste oil was disposed by placing it in the
reserve pit.
Disposal Practices
At the completion of drilling, all cuttings were placed in the
reserve pit. There was no testing of pit contents. There was no
treatment of pit contents. The pit contents were not moved for
final disposition. The fluids were evaporated. The dried pit
solids were buried. The pit site was to be reclaimed by adding
topsoil and reseeding. According to company representatives,
records specific to drilling waste normally are not kept unless
wastes are removed from the reserve pit. Associated records
would be contained in detailed well files.
Permits
The site was operating under Permit No. 49-005-17074 issued on
June 16, 1986 by the WY Oil & Gas Conservation Commission. A
copy of this permit is included in Attachment B.
C-1128
-------
n
i
K)
MUD
FIT
u
PO\A/T
Figure 2. Schematic Diagram of Myers State Well No. 41-16
-------
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Myers State Well No. 41-16 consisted of
one supernatant and one sludge sample. Figure 2 shows the
sampled pit and the location of the sample points. Supernatant
and sludge were collected in the reserve pit. Four quadrants
were established for supernatant and sludge sampling. Sample
points were accessed by boat. There were no discrepancies
between the actual and measured sample point.
Sampling Methods and Equipment
To collect samples, the reserve pit was measured to identify
four quadrants and to locate the center of each quadrant. The
supernatant was collected from the boat using a sampling thief.
Sludge was collected from the boat using a Ponar dredge.
The pit supernatant was tested onsite for pH and free chlorine
content after the completion of sampling. Supernatant pH was
measured at 8. Free chlorine was measured at less than the
lowest detectable level of 0.2 ppm. Due to time constraints, the
samples collected were held in refrigeration overnight and
shipped to the laboratories on July 14, 1986.
C-1130
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1131
-------
C-1132
-------
Photo 1. Reserve pit
Photo 2. Reserve pit
n
I
OJ
*-—--t .- " 1""''''^fc--" - *' ^**j."-^^"'*fc'S"^''~" **** ~ -~'^-ot~Jt
'5%r- „-••-.•<•£•?."*-,$.• \. ""'-r ' \
&tf?'^m$t^.;: -.
%$&$?&$$$£ ^ ••
^^^^•&^'!^- '*••- ft - • ;
Photo 3. Reserve pit
-------
Photo 4. Reserve pit and drilling rig
Photo 5. Reserve pit and generator
O
I
-------
ATTACHMENT B: PERMITS
C-1135
-------
C-1136
-------
r-
..C:
" STA.e OF WYOMING
, OIL AND GAS CONSERVATION COI\
rorm ' Office of State Oil and Gas Supe
j.Duarr.ioeB P.O. Box 2640
Casper, Wyoming 82601
'APPLICATION FOR PERMIT TO: blnn-out preventer program, if any.
If proposal is to dlrcctlonally drill or deepen, give pertinent data on subsurface locations and measured and true
vertical depth.
PROPOSED PORGRAM: Refer to enclosed 9 Point Program.
RECEIVED
KM 1986
WYOMING OIL & .
CONSERVATION COMMISSION
a.
SIGNED,
^ 7rt.QsL.SJ,
Sr. Environment &
TrrT-T! Regulation Engineer
DATE_
2-3-86
STATUS OF DOND
(This space for State office use)
PERMIT NO.
APPROVAL DATE copy (Original Signed)
\pprornls sent.
CONDITIONS OF APPROVAL. IF ANY:
37
-------
Form PS-102
,R. 72 id
c
; t
. «
Q
— 10
Elevation - 4G04_ gr»
120°Eo =J 4603 gr-o
I-
r-
•cr
in
i¥
T.
49
Scale: 1"=1000'
Powers Elevation of Denver, Colorado has'in accordance with a request
from fto PachulsUi for Diamond EhanrocU Exploration Coirpany
determined the location of #41-15 nyoro-stato
tO be 632FH £ 7COFE SeCtlOFl 1C, TOWPShlP 49 »«
Range 72 u0 of ths sixth principal Meridian,
Campboll County, Wycning
I hereby certify that this plat is an
accurate representation of a correct
survey-.showing the location of
#41-16 Hyoro-Stato
Date:
1-24-36
Licensed Land Surveyor No. 337
State of
C-1138
-------
r
MYERS STATE 41-16
NE/NE Sec. 16, T49N, R72W
Campbell County, Wyoming
ESTIMATED FORMATION TOPS
FORMATION
Fort Union
Lance
Fox Hills
Niobrara
Mowry
Muddy
Dakota
Morrison
Sundance
Spearfish
Goose Egg
Forelle
Minnekahta
Opeche
Minnelusa
T.D.
DEPTH
Surface
2,998'
4,443'
7,225'
8,512'
8,694'
8,876'
9,042'
9,156'
9,421'
9,984'
10,238'
10,295'
10,317'
10,337'
10,60.0'
ESTIMATED DEPTHS OF WATER, OIL, GAS OR MINERALS
Oil: Oil is anticipated in the Minnelusa formation.
Gas: Gas is expected in conjunction with oil production in the
Minnelusa formation.
Water: Ground water is anticipated to approximately 250'. Some
brackish water sands could possibly exist below this level;
however, the hydrostatic head of the drilling fluid will
safely contain these waters within their formations.
PROPOSED CASING PROGRAM
Size
Grade
Wt./Ft.
9 5/8" K-55 36#
5V K-55 & N-80 15.5#, 17#,
Condition
New
New
Depth Set
1,000'
10,600'
C-1139
-------
Q C
MYERS STATE 41-16
NE/NE Sec. 16, T49N, R72W
Campbell County, Wyoming
(Page 2)
4. PRESSURE CONTROL EQUIPMENT
A. Refer to Diagram A.
B. Minimum pressure ratings on any and all B.O.P. or related
control equipment will be 3,000///in.
C. B.O.P. stack will be pressure tested to l,000#/in. prior to
drilling out of surface casing. The stack will then be checked
on each trip to insure workability.
5. TYPE AND CHARACTERISTICS OF PROPOSED CIRCULATING MUD
Water to 9,500' - 10,500'. Low solids non-dispersed to T.D.
If conditions necessitate mud-up may be before 9,500'. •
Max. Wt. 9.3
Vis. 55
WL 10 cc
Enough mud and chemical material will be kept on location to
maintain these characteristics.
6. AUXILIARY EQUIPMENT
1. Upper or lower kelly cock.
2. No floats will be used.
3. Visual monitoring of mud pits.
4. One full opening stabbing valve on floor at all times.
7. EVALUATION PROCEDURES
1. Drill Stem Tests: To be determined by on-site geologist,
2. Coring: To be determined by on-site geologist.
3. Logging: IES, Dual Induction and Gamma Ray.
C-1140
-------
c
MYERS STATE 41-16
NE/NE Sec. 16, T49N, R72W
Campbell County, Wyoming
(Page 3)
8. ABNORMAL DRILLING CONDITIONS
1. Abnormal Pressure: None anticipated.
2. Abnormal Temperatures: None anticipated.
3. Hydrogen Sulfide: None anticipated.
9. ANTICIPATED STARTING DATE AND DURATION
We anticipate commencing operations by February 15, 1986, or as
soon as governmental approval is obtained. The anticipated
duration of drilling and completion operations is approximately
six (6) weeks.
C-1141
-------
Pipe Rams
Flexible Coupling
Electric Motor
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UNIT
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Accumulator
-------
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STATE OF WYOMING ^.
'.-,- OFFICE OF =0}.
N9 17074 OIL AND GAS CONSERVATION COMMISSION
.S25.OO
TWENTY-FIVE AND NO/1OO DOLLARS
Well Permit Fee Covering Well No.
Located 1A /V £. 'A AJ C ^ Sec. / (^ T */ / R
SATE OIL AND GAS SUPERVISOR
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c
FORM 14 B
(JULY 1. 1984]
STATE OF WYOMING
OIL AND GAS CONSERVATION COMMISSION
P.O. Box 2640
Casper, Wyoming 82602
FEDERAL FORMS MAY BE SUBMITTED IN LIEU OF FORM 14
IF ALL INFORMATION REQUIRED HEREON IS INCLUDED
(SUBMIT IN DUPLICA'
APPLICATION FOR PERMIT TO USE AND CONSTRUCT Ef
FOR TEMPORARY USE OR FOR RESERVE PIT
I FEB24!*'
HEN PIT
CHECK ONE.
1. NEW PIT A
EXISTING PIT D
RESERVE PIT D
NAME OF OPERATOR
2- Diamond Shamrock Exploration Company
PHONE NO.
307-266-1882
ADDRESS OF OPERATOR
3- P. 0. Box 2530. Mills. Wyoming 82644
LEASE NAME
4- Myers State 41-16
LOCATION (QQSEC. T.R.)
6- NE/NE, Sec. 16. T49N, R72W
COUNTY
Campbell
GROUND ELEVATIOr
5- 4.604'
8.
API WELL NUMBER'
WATER ANALYSIS — TESTS MUST BE MADE IN ACCORDANCE WITH STANDARD METHODS — ATTACH FULL COPY OF
9. ANALYSIS(ES) TO THIS FORM
METHOD OF WATER SAMPLE COLLECTION
LABORATORY PROVIDED RECEPTICAL U OTHER
DATE WATER SAMPLE WAS TAKEN IN THE FIELD I
10. MUD PROGRAM (IF APPLICABLE)
Water to approximately 10,000'. Low solids non-dispersed to T.D.
Tl. ANTICIPATED TIME PERIOD PIT WILL BE IN US'E.
February 15, 1986 through drilling and completion operations.
SIZE OF PIT:
12. LENGTH _L£2_
.FT. WIDTH .
125
. FT. DEPTH .
10
.FT. FREEBOARD.
.FT.
13.
CAPACITY
17
,000
RRIS
14.
ORIGIN OF PIT C
Drilling t
ONTENT
luids.
(FORMATION
IF
PRODUCTION
PIT).
1 5. FINAL DISPOSAL OF PIT CONTENT:
EVAPORATION XX
HAULED
DISPOSAL WELL
(PIT LOCATION)
. (WELL NO. AND LOCATION)
1 6. MAXIMUM FLUID LEVEL ABOVE AVG. GROUND LEVEL.
.FT.
DRAINAGE DISTANCE IN FEET TO CLOSEST FRESH POND, STREAM OR LAKE
Tributary of Donkey Creek NAME
300
.FT.
18. SUBSOIL TYPE
Sandy loam.
1 9. TYPE OF SEALING MATERIAL (Including specifications and Method of Application)
If soil is pourous a coating of bentonite will be applied.
•Number Assigned Well On APD For Reserve Pit: (If Unassigned, Commission Will Provide)
Number Assigned To Well Or One Of The Wells Which Produces Water Going Into Temporary Pit.
(CONTINUED ON REVERSE SID
01 144
-------
c.-
FORM 14 B CONTINUED
20. ADDITIONAL INFORMATION (By attachment include a plan view of the location, a topo map of sufficient size and detail to
determine the surface drainage system complete with all natural waterways and irrigation systems, (if appropriate), and other
information as may be specifically required by the Commission)
Refer to Topographic map.
I HEREBY^ERTIFY THAT THE FOREGOING IS TRUEAND CORRECT Sr. Environment &
SIGNED -~f~,-i^^. ^f> 1 . ^'<=^-^^^^— ' TITI FRegulation Eng. DATF 1-27-86
THIS SPACE FOR COMMISSION USE
APPROVED BY
/ \
V_;
V
— -^V^
1
CONDITIONS OF APPROVAL, IF ANY:
WOAOD/7iVES Off MATERIALS '.VHfCH
BEPRESEWV if-; '•• „-£ PfT. ANY ADDITIV
•""•"« «» >•-
stL-rs^ &upr;in
-T
tuAi r
^s
W!
ZS
v^<^V'^^\c^
c \
vK>
k'>C">
•nTip"MjA-, Vo^\\
LL CONTAMINATE SURFACE OR SUBSURFACE WATER
OR MATERIALS WHICH ARE NOT DESCRIBED !N MUD
HE IIMtUh
CUMPLhIION
Or DRILLING ACTIVIi ItS.
nATFO-I^S-PlC
WILL
C-1145
-------
C-1146
-------
Sampling Report
Investigation of Amoco Production Company's LACT No. 4
Midwest, Wyoming
July 14, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Powder River Basin production sites developed by
the Department of Environmental Quality at the request of EPA.
The list was transmitted via telephone to the EPA contractor on
July 11, 1986. Site selection from this list took place during
the telephone conversation.
The Department of Environmental Quality preferred to list the
possible sample sites as shown below. The EPA contractor had no
interest in the manner the particular sites were listed (by site
name, location, operator, permit number, API number, etc.) as
long as the site could be identified in detail upon selection.
Thus, the EPA contractor had minimal information which kept to a
minimum the amount of bias. No other information was known about
the sites on the list at the time of selection. Detailed
information was obtained only after selection of primary and
back-up sites. The list consisted of five production sites in
.northeast Wyoming:
Operator Permit Number
1. Amoco WYO-0002798
2. Amoco WYO-0002828
3. Amoco WYO-0002836
4. Amoco WYO-0002879
5. Amoco WYO-0002887
6. Amoco WYO-0002909
7. Amoco WYO-30384
8. Conoco WYO-30868
9. MCOR WYO-30264
10. Terra WYO-2445
11. Terra WYO-2453
12. Terra WYO-2348
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
No. 2 on the above list (Amoco WYO-0002828) was selected as the
primary sample site. No. 9 on the above list (MCOR WYO-30264)
was selected as the back-up site in case the primary site proved
inaccessible or inappropriate.
C-1147
-------
Further inquiry indicated the primary site was Amoco Production
Company's LACT No. 4 near Midwest, Wyoming. No problems were
encountered arranging for sampling to be conducted July 14, 1986,
The back-up site was not required.
Site Location
Amoco Production Company's LACT No. 4 is located about 3 miles
northwest of Midwest, WY along Highway 87. Figure 1 is a map
indicating the site.
The site is operated by Amoco Production Co., whose mailing
address and telephone number are:
PO Box 2570
Casper, WY 82601
307-261-3355
Contact Name: Wayne Peterson
Attendees
Sampling of Amoco LACT No. 4 was performed by CENTEC Corporation
personnel on July 14, 1986. The following is a list of people
present at the time of sampling:
CENTEC Corp. (sample team):
State Representatives:
Operator Representative:
American Petroleum
Institute Representatives:
Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
E. J. Fanning, WY Dept. of
Environmental Quality
Tom McCall, WY Oil & Gas
Conservation Commission
Wayne Peterson, District
Foreman
Maurice Jones, Contracted
Observer
David Havis, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
Earl Kinsley, Contracted Sample
Team Member
Site Description
Amoco Production Company's LACT No. 4 is located within the
Powder River Basin in rural foothills; the depth to groundwater
over 100 feet, and the nearest surface water less than 1/2 mile
away. There are no drinking water wells within a 1-mile radius
of this site. The soil in this area is shale. The climate at
this site location is net evaporation.
C-1148
-------
• /-"^VA/,
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SITE LOCATION -;
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-' -' > '> '"' ' (*^' Vc;^!»! . ' VO ' - . ' ' ' •> N ' °J - ••,. ...-'. ' 1."
/."'- '_:-> - - - "£ '- «" . •• ^ • ' • « ''.'' ' ' '! '
. .
-- v c p;;- ,- if. • . -. "".^--' t >:r •.v-v^-i**-;/
:L^ f. C .^V;. -•.... •??i';M • lM''-^"-r^ A.
Figure 1. Location of AMOCO LACT #4, Midwest, Wyoming
C-1149
-------
This site was an oil water separation facility, and is one of
seven production batteries in the Salt Creek Oil Field. Figure 2
is a facility diagram. The facility receives produced waters and
treats them for enhanced oil recovery. The water is then
discharged into the Bothwell Draw. Approximately 120,000 barrels
of water per day are discharged. The produced water comes from
approximately 150 wells. Figure 3 is an analysis of the water
discharge performed on May 12, 1986.
Oil-water separation is achieved by oil skimming. The water
flows through a series of four skimming pits. Effluent from the
final pit is discharged. Photo 1 (in Attachment A) shows the
tank facility and the first two oil skimming pits. Photos 2-6
show the four skimming pits. Photos 7 and 8 show the final
discharge point into the Bothwell Draw. No sludge from drilling
sites is stored or treated at this site.
Representatives from EPA and the Wyoming Department of
Environmental Quality performed a reconnaissance of LACT No. 4 on
July 12, 1986. During the visit, the oil skimmers at the pits
were cleaned of all oily residue, as shown in Photo 9.
Permits
The facility operates under NPDES Permit No. WY-0002828. A copy
of this permit is in Attachment B. Specifics on facility
operation is in Attachment B. The permit contains discharge
limitations and monitoring requirements for total dissolved
solids, oil and grease, chlorides, sulfates, and pH. See permit
for specific numerical limitations.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Amoco LACT No. 4 represent an upstream
production sample and a production discharge sample. The
production discharge sample was collected at the NPDES discharge
point, as shown in Photo 7. The upstream production sample was
taken at one of the treatment pits from a pipeline that removed
water from oil tanks, as shown in Photo 6.
C-1150
-------
U. S. HIGHWAY 87
O
I
(10
ouni uma
DOTHWCLL
DIUV
Figure 2. Schematic Diagram, Amoco Production Co.'s LACT No. 4,
Midv/est, Wyoming
-------
WAMCO LAB
P. O. Box 2953 - Casper, WY 8260;
ANALYSIS REPORT
COMPANY: Amoco Production
Sample type Waters
DATE May 12> 1986
Date Rec'd 5/2/86
W. O. No. 6179
Anal 95. is in Milligrams per Liter except where Noted
Limits of Detection are Noted Following Less Than Mark (<)
Sample No.
Samp 1e Descr.
Total Dissolved Solids
Sulfate 4>
Chi or ide
Oil & Grease Only (O&G)
Samp 1e No .
Samp 1e Descr.
Total Dissolved Solids
Sulfate
Chi oride (CM
pH, Units
OiJ f+ Grease & Sulfur (O&G&S)
Sulfur (S-%)
Oil & Grease Only (O&G)
1
Lact 1
00132798
3140
195
1000
S.48
17.5
43.2
10.6
5
La c t 11
0002887
5773
553
2600
8. 14
32 . 0
77. 2
7.3
2
Lact 4
0002828
3715
276
1 150
8.
6.
-
6.
6
Lact 13
0002909
3306
179
1250
B.
19.
.i.
9.
3
Lact 5
0002836
3257
105
1000
10 8.52
2 18.1
57.2
2 7.7
8
Lease 46
0002941
3480
1460
680
52 7.84
4 0.2
5
9 0.2
i
Lact lli
0002S7S
2 9 46
164
950
8
20
52
9
Figure 3. Laboratory Analysis Report, Amoco Production
C-1152
-------
Sampling Methods and Equipment
The NPDES discharge point consisted of three pipes feeding into
the Bothwell Draw. The liquid production effluent sample was
collected using a stairiless steel bucket and a rope to catch the
water from the pipes.
The upstream production sample was collected using a stainless
steel bucket. The produced water was tested onsite for pH and
free chlorine content at the conclusion of sampling. A pH value
of 8 was recorded. Free chlorine content was less than the
lowest detectable level of 0.2 ppm.
C-1153
-------
C-1154
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1155
-------
C-1156
-------
i»i^»*-5«-i-ViC.i) 1 "-" "l* , - ,
^.^^^W-iW;.- -"-*'.
fsm$*.-•>•&&,'-*~-ie-^\£..' :-• ' '
?wt «fcj*'Jtl l "*" -C »^f'" w^1" "''*-.
n
i
Photo 1. Shipping tanks and skim ponds
Photo 2. Skim ponds
Photo 3.
Skim pond
Photo 4. Skim ponds
-------
O Photo 5. Skim ponds
Photo 6. Skim ponds
Photo 7 - NPOF1 rt I .
-------
n
i
Photo 9. Cleaning of oil skim ponds
-------
C-1160
-------
ATTACHMENT B: PERMITS
C-1161
-------
C-1162
-------
OW-Page 1
Permit No.: Wy-0002828
AUTHORIZATION TO DISCHARGE UNDER THE
NATIONAL POLLUTANT DISCHARGE ELIMINATION SYSTEM
In compliance with the provisions of the Federal Water Pollution Control Act, as
amended (33 U.S.C. 466 et. seq.,) (hereinafter referred to as "the Act"), and the
Wyoming Environmental Quality Act (W.S. 35-11-101 through 1104, specifically
301(a)(i); Laws 1973, ch. 250, Section 1),
Amoco Production Company
is authorized to discharge from a facility located in the
Salt Creek Field, L.A.C.T. #4 SE1/4, Section 23, T40N, R79W, Natrona
County, Wyoming
to receiving waters named
Bothwell Draw
in accordance with effluent limitations, monitoring requirements and other conditions
set forth in Parts I, II and III hereof.
This permit shall become effective on January 1, 1986.
This permit and the author 15^^^%£p^$^scharge shall expire at midnight, December 31,
1990.
Administrator - Wat
Date
December 26, 1985
December 26, 1985
Director - Department of Environmental Quality Date
C-1163
-------
OW-Page 2
PART I
A. EFFLUENT LIMITATIONS AND MONITORING REQUIREMENTS
During the period beginning January 1, 1986 and lasting through December 31,
1990, the permittee is authorized to discharge from outfall(s) serial number(s)
001.
Such discharges shall be limited and monitored by the permittee as specified
below:
Effluent Characteristic Discharge Limitations
mg/1 mg/1
Daily Max Instantaneous Max
Flow - MGD N/A N/A
Total Dissolved Solids N/A 5000
Oil and Grease N/A 10
Chlorides N/A 2000
Sulfates N/A 3000
The pH shall not be less than 6.5 standard units nor greater than 8.5 standard units
in any single grab sample.
There shall be no discharge of floating solids or visible foam in other than trace
amounts.
Monitoring Requirements
Parameter Measurement Frequency Sample Type
Flow - MGD Every 6 months Instantaneous
Total Dissolved Solids Every 6 months Grab
Oil and Grease Quarterly Grab
Chlorides Every 6 months Grab
Sulfates Every 6 months Grab
pH Every 6 months Grab
Samples taken in compliance with the monitoring requirements specified above shall be
taken at the following location(s): At the outfall of the final treatment unit and
prior to admixture with diluent waters.
C-1164
-------
OW-Page 3
B. MONITORING AND REPORTING
1. Representative Sampling
Samples and measurements taken as required herein shall be representative
of the volume and nature of the monitored discharge. All samples shall be
taken at the monitoring points specified in this permit and, unless other-
wise specified, before the effluent joins or is diluted by any other
wastestream, body of water, or substance. Monitoring points shall not be
changed without notification to and approval by, the permit issuing author-
ity.
2. Reporting
Monitoring results obtained during the previous 6 month(s) shall be sum-
marized and reported on a Discharge Monitoring Report Form, postmarked no
later than the 28th day of the month following the completed reporting
period. The first report is due on July 28, 1986. Duplicate signed copies
of these and all other reports required herein, shall be submitted to the
Regional Administrator and the State at the following addresses:
U.S. Environmental Protection
Agency
One Denver Place
999 18th Street, Suite 1300
Denver, Colorado 80202-2413
Attention: Enforcement-Permits
Telephone: (303) 837-4901
Wyoming Department of Environmental
Quality/Water Quality Division
Herschler Building
122 West 25th Street
Cheyenne, Wyoming 82002
Telephone: (307) 777-7781
If no discharge occurs during the reporting period, "no discharge" shall be
reported. If discharge is intermittent during the reporting period, sam-
pling shall be done while the facility is discharging.
Definitions
a.
b.
c.
d.
The "daily average" discharge means the total discharge by weight
determined by the arithmetic mean (geometric mean in the case of the
fecal coliform parameter) of a minimum of three (3) samples taken on
three (3) separate days during a calendar month.
The "daily maximum" shall be determined by the analysis of a properly
preserved composite sample composed of a minimum of four (4) grab sam-
ples collected at equally spaced two (2) hour intervals and propor-
tioned according to flow at the time of sampling.
The "daily maximum" concentration shall be determined by the analysis
of a properly preserved composite sample composed of a minimum of four
(4) grab samples collected at equally spaced two (2) hour intervals
and proportioned according to flow at the time of sampling.
The "instantaneous maximum" concentration shall be determined by
analysis of a single properly preserved grab sample.
the
C-1165
-------
OW-Page A
Test Procedures
Test procedures for the analysis of pollutants, collection of samples, sam-
ple containers, sample preservation, and holding times, shall conform to
regulations published pursuant to Section 304(h) of the Federal Water Pol-
lution Control Act.
5. Recording of Results
For each measurement or sample taken pursuant to the requirements of this
permit, the permittee shall record the following information:
a. The exact place, date and time of sampling;
b. The dates the analyses were performed;
c. The person(s) who performed the analyses;
d. The analytical techniques or methods used; and
e. The results of all required analyses.
6. Additional Monitoring by Permittee
If the permittee monitors any pollutant at the location(s) designated
herein more frequently than required by this permit, using approved analyt-
ical methods as specified above, the results of such monitoring shall be
included in the calculation and reporting of the values required in the
Discharge Monitoring Report Form. Such increased frequency shall also be
indicated.
7. Records Retention
All records and information resulting from the monitoring activities
required by this permit including all records of analyses performed and
calibration and maintenance of instrumentation and recordings from continu-
ous monitoring instrumentation shall be retained for a minimum of three (3)
years, or longer if requested by the Regional Administrator or the State
water pollution control agency.
8. Facility Identification
All facilities discharging produced water shall be clearly identified with
an all-weather sign posted at a visually prominent location. This sign
shall, as a minimum, convey the following information:
a. The name of the company, corporation, person or persons who hold(s)
the discharge permit; and
b. The name of the facility (lease, tank battery number, etc.) as identi-
fied by the discharge permit.
C-1166
-------
OW-Page 5
PART II
A. MANAGEMENT REQUIREMENTS
1. Change in Discharge
All discharges authorized herein shall be consistent with the terms and
conditions of this permit. The discharge of any pollutant identified in
this permit more frequently than or at a level in excess of that authorized
shall constitute a violation of the permit. Any anticipated facility
expansions, production increases or process modifications which will result
in new, different or increased discharges of pollutants must be reported by
submission of a new NPDES application or, if such changes will not violate
the effluent limitations specified in this permit, by notice to the permit
issuing authority of such changes. Following such notice, the permit may
be modified to specify and limit any pollutants not previously limited.
2. Noncompliance Notification
If, for any reason, the permittee does not comply with or will be unable to
comply with any maximum effluent limitation specified in this permit, the
permittee shall provide the Regional Administrator and the State with the
following information, in writing, within five (5) days of becoming aware
of such condition:
a. A description of the discharge and cause of noncompliance; and
b. The period of noncompliance, including exact dates and times; or, if
not corrected, the anticipated time the noncompliance is expected to
continue, and steps being taken to reduce, eliminate and prevent
recurrence of the noncomplying discharge.
3. Facilities Operation
The permittee shall at all times maintain in good working order and operate
as efficiently as possible all treatment or control facilities or systems
installed or used by the permittee to achieve compliance with the terms and
conditions of this permit.
4. Adverse Impact
The permittee shall take all reasonable steps to minimize any adverse
impact to navigable waters resulting from noncompliance with any effluent
limitations specified in this permit, including such accelerated or addi-
tional monitoring as necessary to determine the nature and impact of the
noncomplying discharge.
5. Bypassing
Any diversion from or bypass of facilities necessary to maintain compliance
with the terms and conditions of this permit is prohibited, except (i)
where unavoidable to prevent loss of life or severe property damage, or
(ii) where excessive storm drainage or runoff would damage any facilities
necessary for compliance with the effluent limitations and prohibitions of
C-1167
-------
OW-Page 6
this permit. The permittee shall promptly notify the Regional Administra-
tor and the State in writing of each such diversion or bypass.
6. Removed Substances
Solids, sludges, filter backwash or other pollutants removed in the course |
of treatment or control of wastewaters or intake waters shall be disposed
of in a manner such as to prevent any pollutant from such materials from
entering navigable waters.
7. Power Failures
In order to maintain compliance with the effluent limitations and prohibi-
tions of this permit, the permittee shall either:
a. In accordance with the Schedule of Compliance contained in Part I,
provide an alternative power source sufficient to operate the wastewa-
ter control facilities;
or, if such alternative power source is not in existence and no date
for its implementation appears in Part I,
b. Take such precautions as are necessary to maintain and operate the
facility under his control in a manner that will minimize upsets and
insure stable operation until power is restored.
B. RESPONSIBILITIES
1. Right of Entry
The permittee shall allow the head of the State water pollution control i
agency, the Regional Administrator and/or their authorized representatives,
upon the presentation of credentials:
a. To enter upon the permittee's premises where an effluent source is
located or in which any records are required to be kept under the
terms and conditions of this permit; and
b. At reasonable times to have access to and copy any records required to
be kept under the terms and conditions of this permit; to inspect any
monitoring equipment or monitoring method required in this permit; and (,
to sample any discharge of pollutants.
2. Transfer of Ownership or Control
In the event of any change in control or ownership of facilities from which
the authorized discharges emanate, the permittee shall notify the succeed-
ing owner or controller of the existence of this permit by letter, a copy;
of which shall be forwarded to the Regional Administrator and the State
water pollution control agency.
3. Availability of Reports
Except for data determined to be confidential under Section 308 of the Act,
all reports prepared in accordance with the terms of this permit shall be
C-1168
-------
OW-Page 7
available for public inspection at the offices of the State water pollution
control agency and the Regional Administrator. As required by the Act,
effluent data shall not be considered confidential. Knowingly making any
false statement on any such report may result in the imposition of criminal
penalties as provided for in Section 309 of the Act.
4. Permit Modification
After notice and opportunity for a hearing, this permit may be modified,
suspended or revoked in whole or in part during its term for cause includ-
ing, but not limited to, the following:
a. Violation of any terms or conditions of this permit;
b. Obtaining this permit by misrepresentation or failure to, disclose
fully all relevant facts; or
c. A change in any condition that requires either a temporary or perma-
nent reduction or elimination of the authorized discharge.
d. If necessary to comply with any applicable effluent standard or limi-
tation issued or approved under Sections 301(b)(2)(C) and (D),
304(b)(2) and 307(a)(2) of the Clean Water Act, if the effluent stan-
dard or limitation so issued or approved:
(1) Contains different conditions or is otherwise more stringent than
any effluent limitation in the permit; or
(2) Controls any pollutant not limited in the permit.
5. Toxic Pollutants
Notwithstanding Part II, B-4 above, if a toxic effluent standard or prohi-
bition (including any schedule of compliance specified in such effluent
standard or prohibition) is established under Section 307(a) of the Act for
a toxic pollutant which is present in the discharge and such standard or
prohibition is more stringent than any limitation for such pollutant in
this permit, this permit shall be revised or modified in accordance with
the toxic effluent standard or prohibition and the permittee so notified.
6. Civil and Criminal Liability
Except as provided in permit conditions on "Bypassing" (Part II, A-5) and
"Power Failures" (Part II, A-7), nothing in this permit shall be construed
to relieve the permittee from civil or criminal penalties for noncompli-
ance.
7 - Oil and Hazardous Substance Liability
Nothing in this permit shall be construed to preclude the institution of
any legal action or relieve the permittee from any responsibilities, lia-
bilities or penalties to which the permittee is or may be subject under
Section 311 of the Act.
C-1169
-------
OW-Page 8
8. State Laws
Nothing in this permit shall be construed to preclude the institution of
any legal action or relieve the permittee from any responsibilities, lia-
bilities or penalties established pursuant to any applicable State law or
regulation.
9. Property Rights
The issuance of this permit does not convey any property rights in either
real or personal property, or any exclusive privileges, nor does it autho-
rize any injury to private property or any invasion of personal rights, nor
any infringement of Federal, State or local laws or regulations.
10. Severability
The provisions of this permit are severable, and if any provision of this
permit, or the application of any provisions of this permit to any circum-
stance, is held invalid, the application of such provision to other circum-
stances, and the remainder of this permit, shall not be affected thereby.
01 170
-------
OW-Page 9
PART III
A. OTHER REQUIREMENTS
1. Flow Measurement
At the request of the Director of the Wyoming Department of Environmental
Quality, the permittee must be able to show proof of the accuracy of any
flow measuring device used in obtaining data submitted in the monitoring
report. The flow measuring device must indicate values within ten (10)
percent of the actual flow being measured.
208(b) Plans
This permit may be modified, suspended or revoked to comply with the provi-
sions of any 208(b) plan certified by the Governor of the State of Wyoming.
C-1171
-------
C-1172
-------
Sampling Report
Investigation of Waste, Incorporated's
Lawrence Brown Disposal Lagoon
Uinta County, Wyoming
July 15, 1986
SITE INFORMATION
Site Selection
EPA specifically selected the Waste Inc.'s Lawrence Brown
Disposal Lagoon facility to obtain technical information and
analytical data regarding the regional practice of using
centralized pits for disposal of wastes from multiple oil and/or
gas sources. More detailed information about the rationale for
selection of centralized disposal pits is contained in Appendix B
of the EPA Technical Report (EPA 530-SW-87-005).
EPA worked cooperatively with the Wyoming Department of
Environmental Quality to identify and select the Waste Inc.'s
Lawrence Brown Disposal Lagoon. No problems were encountered
arranging for sampling to be conducted on July 15, 1986.
Site Location
Lawrence Brown Disposal Lagoon is located 5 miles from Woodroff
Narrows Reservoir, north of Evanston. Figure 1 is a map
indicating the disposal site.
The site is operated by Waste, Incorporated, whose mailing
address and telephone number are:
PO Box 133
Evanston, WY 82930
307-789-3533
Contact Name: Rayo Barker
Attendees
Sampling of Lawrence Brown Disposal Lagoon was performed by
CENTEC Corporation personnel on July 15, 1986. The following is
a list of people present at the time of sampling:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
State Representative: E. J. Fanning, WY Dept. of
Environmental Quality
Operator Representative: Gary Ellingford, President,
Waste, Inc.
C-1173
-------
~*
\;
-. -
..
; »•, — -— ^ " 1
% ' . : V A . - \
~cf ~ - ; •-. (l/^ .,-
J7 1 \ ~U( ^ Cr«,ll*
/."••* \ .' ' ' "" •
r ««««rf-- — . l ;
* .''' X : •. N J • -,<-
-•.^' ,iV,,,,..r ,' "v^:"-^"
Figure 1. Location of Lav/rence Brown Disposal Lagoon,
Uinta County, Wyoming
C-1174
-------
American Petroleum
Institute Representatives:
Alan Wilson, Contracted Sample
Team Member
Earl Kinsley, Contracted Sample
Team Member
David Havis, Contracted
Observer
Site Description
Lawrence Brown Disposal Lagoon is located in a rural foothill
area; the depth to groundwater is 30 feet, and the nearest
surface water is less than 1/2 mile away. There are no drinking
water wells within a 1-mile radius of the site. The soil in this
area is dense clay. The climate at this site is net evaporation.
This site is a central pit facility for mud and brine. Fig-
ure 2 is a schematic diagram of the disposal site. Three
separate pits have been constructed for the site. The pits are
constructed 50 percent above grade and 50 percent below grade.
The pits are lined—one with a polyliner and two with clay- Leak
detection monitoring is required._ Each pit had a series of
drains with gravel inside designed to catch any leakage if the
pit liner is punctured. The pits receive a variety of materials
including fresh water, produced water, drilling mud, trash, waste
oil, and sewage. These fluids are trucked to the facility- The
individual pits are not fenced; however, the entire site has a
fence around the property line.
Only one pit was sampled. The cost to build this pit was
$230,000. Consultant costs were $23,000. This pit measures 400
feet by 400 feet. On the day of sampling, the liquid level in
the pit was 3 feet. The sludge depth was about 1 inch except for
the dumping area where the depth was 0.5-1 foot. The facility
had no plans to treat any of the pits. When the pits are to be
closed, the fluids will be evaporated and the dried solids
buried. The site will be reclaimed by the addition of topsoil
followed by reseeding. Photos 1-5 (Attachment A) show the pit
that was sampled. Photos 6-11 show the other two pits at the
site.
Permits
Each pit at the facility has a separate permit issued by the
Wyoming Department of Environmental Quality (Permit Nos. 82-140,
83-82, and 84-547R). The pit selected for sampling operates
under Permit No. 84-547R. A copy of this permit is shown in
Attachment B.
C-1175
-------
IN/VUO
PIT
CENTRALIZED
MOD
PIT
Jf
f AREA
C£WTR,AL12£D
AMD
PIT
Figure 2. Lawrence Brown Disposal Lagoon Site
Schematic Diagram
C-1176
-------
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Lawrence Brown Disposal Lagoon consisted
of one supernatant sample and one sludge sample. Figure 2 shows
the sampling locations within the pit. The sampled pit was
chosen because it was the only pit at the facility that was still
receiving fluids at the time of sampling. The other two pits had
not received fluids since October 1985.
Sampling Methods and Equipment
The pit was measured to identify four quadrants and the center of
each quadrant. The liquid sample was collected from the boat
using the sampling thief. Weather conditions on the day of
sampling (40 mph winds) prevented the liquid collection at the
four precise quadrant locations as defined in sampling protocols.
Two established quadrants were sampled at midpoint. The
remaining sample was collected from various points in the other
two quadrants.
The sludge sample was collected using a stainless steel spoon and
bucket from the northeast pit corner. This was the location of
truck unloading into the pit, and nearly all sludge was located
at this corner. Photo 12 shows this corner of the pit. The
sample was not collected with the coring tube or the dredge at
the request of the onsite representative for fear that the pit
liner would be punctured.
The lagoon supernatant was tested onsite for pH and free chlorine
after the completion of sampling. Test results gave a pH value of
6. Free chlorine was less than the lowest detectable level of
0.2 ppm.
C-1177
-------
C-1178
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1179
-------
C-1180
-------
", -' :- -! -, - , —-•; l•'^^^<•^t«r:J?^C^KlJ^i^;
Photos 1,2,3. Sampled central mud and brine pit
n
I
GO
ffi$fSfcp^fft£•'"•3^ ''''*-:'>^'S': "4r^'-?'j-!f•^T^'^J-'' ^"-Vi
r- -
-'^v-:^M*v::V:; ;
-.'^I/v.v.,.-h.;-.^->,t^t.^_-.^. A •
^^^.Sg^a^^i^^gg^^: i^.-. :..•• •
^J^aS^&^SS^iS^^SS^SSS
Photos 4,5. Sampled central mud and brine pit
-------
O
CD
to
TXBVftmr-r**"- '--
Mgjjtplriiaift-S'f it--UL.
Photos 6,7. Lawrence Brown central mud and brine pit - not sampled
-------
n
i
c»
U)
Photos 10,11. Lawrence Brown central mud and brine pit - not sampled
Photo 12. Sludge sample point location
-------
C-1184
-------
ATT/TCHMENT B: PERMITS
C-1185
-------
C-1186
-------
PERMIT TO CONSTRUCT
New Permit No. 84-547R
/ / Renewal
/~7 Modified
Lawrence Brown Disposal Lagoon
(Name of Facility)
This permit hereby authorizes the applicant (name and address):
Waste, Inc.
P.O. Box 133
Evanston, WY 82930
to construct, install, or modify a synthetically lined pond for disposal
of petroleum industry sludges and wastewater .....
facility according to the procedures and conditions of the
application No. 84 547R The facility is located in ____;
Sec. 7, T17N, R120W
— —— \
in the.. County of Uinta
in the State of Wyoming. This permit shall be effective for a period of two (2)
years (five (5) years maximum) from the date of issuance of this permit.
The issuance of this permit provides that the Department of Environmental Quality has
evaluated and determined that the application meets minimum applicable construction
and design standards. The compliance with construction standards and the operation
and maintenance of the facility to meet the applicant's engineer's design are the
responsibility of the applicant, owner, or operator.
The authority to construct granted by this permit does not mean or imply that the
Wyoming Department of Environmental Quality guarantees or insures that the permitted
facility, when constructed, will meet applicable discharge permit conditions or other
effluent or operational requirements.
Nothing in this permit constitutes an endorsement of the construction or the design
of the facility described herein. This permit indicates only that standards of
design and construction required by the Environmental Quality Act have been met. The
State assumes no liability for, and does not in any way guarantee the performance of,
the permittee in the exercise of its activities allowed under this permit. The Per-
mittee understands that it is solely responsible to any third parties for any liabil-
ity arising from the construction or operation of the facility described herein. By
the issuance of this permit, the State does not in any way waive its sovereign immu-
nity.
The permittee shall allow authorized representatives from the Department of Environ-
mental Quality, Water Quality Division, upon the presentation of credentials and dur-
C-1187
-------
ing working hours, to have access to inspect the facilities, at the above location,
for-the purpose of compliance with the provisions of this construction permit.
The permittee shall notify representatives from the Department of Environmental Qual-
ity, Water Quality Division the day construction commences and give an estimate of
completion of the project. The authorized representative in your area can be con-
tacted at the following address: District Engineer, State of Wyoming, Department of
Environmental Quality, Water Quality Division, 210 Lincoln, Lander, Wyoming 82520;
telephone, 332-3144.
Nothing in this permit shall be construed to preclude the institution of any legal
action or relieve the permittee from any responsibilities, liabilities or penalties
established pursuant to any applicable State law or regulation.
The issuance of this permit does not convey any property rights in either real or
personal property, or any exclusive privileges, nor does it authorize any injury to
private property or any invasion of personal rights, nor any infringement of Federal,
State or local laws or regulations.
AUTHORIZED BY:
Adminr
Water Qu
May 20,
Director
Dept. of Environmental Quality
Date of Issuance
This permit does not supercede the requirements for obtaining any permit from local
agencies.
C-1188
-------
Sampling Report
Investigation of Sun Exploration and Production Company's
Luckey Ditch Fed B Well No. 4
Uinta County, Wyoming
July 16, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). Although EPA worked with the
Department of Environmental Quality and the Oil and Gas
Conservation Commission to identify appropriate drill sites prior
to the public meeting scheduled for July 11, 1986, no list of
sites was forthcoming.
The list of possible sample sites was presented to EPA by the Oil
and Gas Conservation Commission at a public meeting held in
Casper, Wyoming, on July 11, 1986. Attendees included
representatives from EPA, Wyoming Department of Environmental
Quality, Wyoming Oil and Gas Conservation Commission, oil and gas
companies, and the public. EPA requested identification of a
number of drill sites at or very near completion during July
16-17, 1986, in the Evanston, Wyoming area for site selection
purposes. The Wyoming Oil and Gas Commission identified the only
site: Sun Exploration and Development Company's Luckey Ditch Fed
B Well No. 4. Since no other sites could be identified by
meeting attendees, the Luckey Ditch site was selected.
The site operator and telephone number were relayed to the EPA
contractor July 15, 1986. Repeated attempts to contact the rig
were unsuccessful. Thus, further information regarding the site
was not available to the sampling team prior to the sampling
date, July 16, 1986.
Site Location
Luckey Ditch Fed B Well No. 4 is located about 20 miles southeast
of Mountain View, Wyoming. Figure 1 is a map indicating the well
site.
The site is operated by Sun Exploration and Production Co., whose
mailing address and telephone number are:
PO Box 5940
Denver, CO 80217
303-696-3500
Contact Name: Bill Brawley
C-1189
-------
Figure 1. Location of Luckey Ditch Fed B Well #4, Uinta County,
Wyoming
C-1190
-------
Attendees
Sampling of Luckey Ditch Fed B Well No. 4 was performed by CENTEC
Corporation personnel on July 16, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representatives:
Operator Representatives:
American Petroleum
Institute Representatives;
Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
E. J. Fanning, WY Dept. of
Environmental Quality
Tom McCall, WY Oil and Gas
Conservation Commission
Ron Coats, Specialist Drilling
Foreman
Bert Bates, Jr., Regional
Environmental Coordinator
Alan Wilson, Contracted Sample
Team Member
Earl Kinsley, Contracted
Sample Team Member
David Havis, Contracted
Observer
Site Description
Luckey Ditch Fed B Well No. 4 is located in a rural mountainous
area. The depth to groundwater is over 100 feet, and the nearest
surface water is over 2 miles away. There are no drinking water
wells within a 1-mile radius of the site. The soil in this area
is rock and clay. The climate at this site is net evaporation.
This site was a developmental gas drilling site. The well
drilling began on July 7, 1986, with an estimated completion date
of September 15, 1986. On the day of sampling, the well was at a
depth of 3,519 feet. The final completion depth was planned at
15,900 feet. Drilling was accomplished with low-solid non-
dispersed muds. Three hundred pounds of biocide Dowicide G were
used on July 24, 1986, to control bacterial growth during the
initial phase of drilling.
Figure 2 is a schematic diagram of the drilling site. Two
separate pits were constructed for the site: a reserve pit and a
mud recirculation pit. The pits were constructed below grade.
Each pit measured 163 feet in length by 83 feet in width. Both
pits were lined with natural clay. The total cost of pit
construction was $6,000. The pits received drilling muds, fresh
water, and motor oil. The pit area was fenced. Diversion
ditches were required. Photos 1 and 2 (Attachment A) show the
two mud pits and the mud recirculator. Photo 3 shows the
drilling rig. Photos 4 and 5 show the operation trailers.
C-1191
-------
o
I
10
m
- A.
WES EL 0'_
MUD
111
\JA
rn
MUD
m
n
-------
A mud recirculation system was used at this site. The two-pit
system was designed so that the first pit would receive all muds
and fluids. Cuttings would remain in the first pit. Supernatant
and reusable drilling mud would flow into the second pit. There,
the muds were removed from the pit bottom and reused. The
supernatant remained in the second pit giving it an iron orange
color. The fluids were piped from drilling operations into the
pit. The sludge depth in the reserve pit was 1-2 feet. There
was no discrete liquid surface in the reserve pit. There was a
liquid depth of 1 foot in the recirculation pit. The total
volume of drilling fluids in the reserve pit was estimated to be
between 2,500 and 5,000 bbl.
A total of 800 bbl of diesel oil was stored in tanks at this
facility. It was unknown how much waste diesel oil would be
generated.
Disposal Practices
At the completion of drilling, all cuttings were placed in the
reserve pit. There was no required testing of pit contents. Pit
contents were to be treated by pH adjustment and settling. The
pit fluids were to be removed and hauled to a disposal pit. The
dried pit solids were buried. The pit site would be reclaimed by
the addition of new top soil and reseeded back to forest.
According to site personnel, there are records available
regarding the final disposition.
Permits
The site was operating under Permit No. W-61811, issued on June
26, 1986, by the Bureau of Land Management. A copy of the permit
is shown in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Luckey Ditch Fed B Well No. 4 consisted
of one supernatant and one sludge sample. Figure 3 shows the
sampled pits and the location of the sample points. Supernatant
was collected in the mud recirculation pit. This was done
because the reserve pit held no discrete liquid surface yet all
liquid in the recirculation pit passed through the reserve pit.
C-1193
-------
6
MUDREORCULATIOA/ FIT
Oo
I
D\KE
0 -T
h
0-
^^J _ J^^ ^ /» b_ «-^ t f ^™ ^\ I ^^™
UI
-1
cw
O
O
Figure 3. Sampled Reserve and Mud Recirculation Pits
01194
-------
Sludge was collected from the reserve pit. Four quadrants were
established for supernatant sampling.
There were no discrepancies between the actual and measured
sample points for supernatant sampling. For sludge sampling, the
four-quadrant procedure was modified because the reserve pit had
a boglike consistency and was inaccessible by boat or by foot. A
sludge sample was collected along the only accessible side of the
pit.
Sampling Methods and Equipment
To collect samples from the mud recirculation pit, the pit was
measured to identify the four quadrants and to locate the center
of each quadrant. The liquid was too shallow for thief sampling;
the supernatant was sampled from the boat with a stainless steel
bucket.
The boat could not be used in the reserve pit, and the pit was
judged unsafe to wade into. The coring tube was not used as the
sludge was too fluid to remain in the coring tube. The sludge
was collected from the pit edge with the dredge, a stainless
steel spoon, and the stainless steel bucket. A sludge sample
depth of 1 foot below pit surface was achieved. This particular
sludge sample was a grab and not a composite.
The pit supernatant was tested onsite for pH and free chlorine
content after completion of the sampling. The pH of the water
was 6; the free chlorine content was less than 0.2 ppm, the
lowest detectable level.
Due to time constraints, the samples were held overnight under
refrigeration before shipment to the laboratories.
C-1195
-------
C-1196
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1197
-------
C-1198
-------
Photo 1. Mud recIrcuIator and reserve pit
Photo 2. Reserve and mud recIrcuI at Ion pits
n
I
vc
IP
Photo 3. Or I I I Ing rig
-------
Photo 4. Operation trailers
Photo 5. Operation trailers
-------
ATTACHMENT B: PERMITS
01201
-------
C-1202
-------
Form 1
January. 1966
STATE OF WYOMING
OIL AND GAS CONSERVATION COMMISSION
Office of State Oil and Gas Supervisor
P. O. Box 2640
Casper. Wyoming 82602
'APPLICATION FOR PERMIT TO:
DRILL
(Submit In Duplicate, Triplicate on State Lands) [
DEEPEN
5 State Lease No.
Unit Agreement
7. Farm or Lease Name
PLUG BACK Qj |_uckey Ditch Fed "B"
OIL I 1 GAS i 1
WELL i 1 WELL 1 1 OTHER
J. OPERATOR
Sun Exploration & Production Company
3 ADDRESS
P.O. Box 5940 T.A., Denver, CO 80217
4 :.crAT)ON'. Show quarter-quarter description and footage measuremt
At surface
NWNE 496' FNL & 1620' FEL
Ai proposed prod, zone
14 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR
Approx (8) miles W/SW of Lonetree. WY
15 DISTANCE IN FEET FROM PROPOSED-
1_
-------
- c
r;
4-
o
C
Forrr. 3160-5 UNITED STATES SUBMIT IN TRIPLICATE-
[Fo™erbiyV-3S33i) DEPARTMENT OF THE INTERIOR {SaW™"0" " *
BUREAU OF LAND MANAGEMENT
SUNDRY
NOTICES AND REPORTS ON WELLS
WELL 0 ^LL D OT.E.
2. NAXE OF OrEEATOa
SUN EXPLORATION AND PRODUCTION CO.
3. AooaEss or O«BATOB
P O..BOX 5940 T.A. , DENVER, COLORADO 80217
; LOCATION or M-CLL (Report location clearij and In accordant* with anj State requirement!. •
See also spaw 17 below.)
At lurface
-W^. FNL , -Wee1- FEL NWJ NEJ SECTION 19-T12N-R114W
It. PERMIT »o.
9257 ''GR
Budget Bureau No. lOO-i-OPS
Expires August 31. 1985
5. LEABE DESIGNATION AND BEaUL HO, ~
W-61811
6. IT; INDIAN. ALLOTTEE Oa T1I1I Kim"
N/A
LUCKEY DITCH UNIT
LUCKEY DITCH FEDERAL "B
4
10. riCLD AND FOOL, OB WILDCAT
LUCKEY DITCH
11. SBC. ±_ i_ x_ or »rr. AMD
BOBTEI OB AUA
SEC. 19-12N-114W
UINTA WY
16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE Or INTENTION TO .' (OBBEQOINT KMFOIX OT '. ''
TEST WATEE SBOT-OIT
ntACTOBt T»EAT
SHOOT Oa ACIDIEI
ncrAia WELL
(Otbcr)
rCLL Oa ALTEX CASI.VO
JlULTlfLE COMri.CTt
ABANDON-
CHANCE PLANS
WATEE saOT-orr
riACTOBE TBEATKENT ___
3BOOTJNO OB ACIOISINS
BXTAIUNO WELL
ALTImINC CASINO
ABANDONMENT'
(NOTE: Report reaulta of moltlpie completion on Well
Completion or Recoapletlon Report and Lot form.)
ntnt u thia work.) •
SUNDRY NOTICE TO CHANGE THE DRILLING PLAN. DUE TO PROBLEMS ASSOCIATED WITH COAL SEAMS I!
THE FT. UNION AND MESAVERDE. THE CASING DESIGN HAS BEEN CHANGED"TO THE FOLLOWING.
HOLE SIZE
171
121
DEPTH
0-500
500-11,000
11,000-TD
CASING SIZE
13 3/8
9 5/8
5 1/2
ATTACHED IS THE REVISED 8 POINT PLAN WHICH SHOWS THE WEIGHTS AND GRADES OF EACH CASING
STRING.
18. I bereor certtfj tnat the Jortrolur ^ trje aod correct
SICKED TITLE .
DATB.
(Tali *pace for Federal or State office DM)
APPROVED BT
CONDITIONS OF APPROVAL. IF
TITLE .
DATS .
, . *See Instructions on Reverse Side
Title IS U.S.C. Sec::on 1001, makes it a crisie for any person know>L-.;iy and willfully to make to any department or agency of
Unuea Slates any filse, .'icutious or fraudulent statements or re-pre-pjsgs^ions as to any matter within its jurisdiction.
-------
SUN EXPLORATION AND PRODUCTION COMPANY .
Lease # W-61811, Luckey Ditch Federal "B" #4
NWi NEJ Section 19, T12N - R114W
Uinta County, Wyoming
Brining Prognosis
1. Estimated Tops of Geologic Markers
Bridger Surface
Green River/Wasatch 1,408'
Fort Union 8,392'
Coal Seams 9,042-10,692'
Mesaverde 10,942'
Milliard 12,913'
Frontier 15,199'
Mowry 15,353'
Dakota 15,574'
TD 15,900'
2. Estimated Depths of Anticipated Water, Oil, Gas or Mineral Formations
Green River/Wasatch 1,408' Water Possible
Fort Union 8,392' Water Possible
Mesaverde 10,942' Oil/Gas Possible
Frontier 15,199' Oil/Gas Possible
Dakota 15,574' Oil/Gas Possible
If any shallow water zones are encountered, they will be adequately
protected and reported; none anticipated. Potentially productive
hydrocarbon zones will be cemented off.
3. Pressure Control Equipment
A. Interval(s) at which used: 0-500'
None
B. Interval(s) at which used: 500-15,900'
Type: 13-5/8" Double Gate Hydraulic, 13-5/8"
Annular Preventer equipped with hydraulic
choke and manifold.
1P3/969 - 1 C-1205
-------
C
3. Pressure Control Equipment (Continued)
Pressure Rating: 10,000 psi working pressure BOP's
5,000 psi working pressure annular
10,000 psi manifold
Testing Procedure: The BOP and choke manifold will be
tested to.70% of the internal yield of
the casing or rated working pressure
whichever is less. The annular preventer
will be tested to 1/2 of rated working
pressure. The test will be for a period
of 15 minutes upon installation, once
every thirty days and/or when flange
seals are broken if a "nipple up" or
"nipple down" takes place.
The fill line will be 3", kill line will be 3" and choke line
will be 4". BOP drills and tests will be recorded in the
drillers log.
The choke manifold and BOP extension rods and handwheels will be
located outside the substructure. The hydraulic BOP closing
unit will be located at least 25 feet from the wellhead in the
accumulator house, with a remote control unit on the rig floor
available to the driller. Exact locations and configurations
will depend upon the particular rig layout.
4. The Proposed Casing and Cementing Program
A. Casing Program
Hole Size Casing Size Wt/Ft Grade Joint Depth Set String Length
171 13-3/8 54.Si K-55 BTC 0-500' 500'
124 9-5/8 43.5# N-80 LTC 0-9000' 9000'
124 9-5/8 47# N-80 LTC 9000-11,000' 2000'
81 5-1/2 20# S-95 BTC 0-3200' 3200'
8i 5-1/2 20i? N-80 LTC 3200-11,600' 8400'
81 5-1/2 23$ N-80 LTC 11,600-15,900' 4300'
2-7/8* 6.5# N-80 EUE 0-15,900' 15,900'
* Production tubing if well is productive.
Casing strings will be tested to .2 psi/ft or 1000' whichever is greater
prior to drilling out. Conductor pipe will not be tested.
C-1206
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4. The Proposed Casing and Cementing Program (Continued)
B. Cementing
Surface Casing: 350 sacks Dowel! Lite w/3£ CaCl2 and
il/sx D-29, followed by 150 sacfes Class
"G" w/335 CaCl? and i#/sx D-29.
TOC - Surface
Intermediate Casing: 825 sacks Class "G" w/.5% D-60.
Estimated TOC - 9000' w/50% excess.
Production Casing: 350 sacks Class "G" w/l£ D-60, 30% D-66,
3% KCL and retarder as needed followed
by 350 sacks Class "G" w/30% D-66, 2.5
gal/sx D-600, 3% KCL and retarder as
needed. Estimated TOC - 12,900' w/30%
excess.
Cement volumes will be adjusted to ensure that all potentially
productive hydrocarbon zones are cemented off. The actual top
of cement will be determined from logs.
5. Mud Program
Interval Type Weight Viscosity Fluid Loss
0-500 Fresh water with 8.6-8.8 30-40 NC
gel & lime sweeps
500-800 LSND w/ASP-700 and 8.6-9.0 30-40 NC
Gel & lime sweeps
8000-11,000 LSND w/gel, lime, 8.8-9.4 38-45 15-30
caustic, ASP-700,
shale stabilizer as
needed
11,000-14,750 LSND w/weight as 9.5-12.0 38-45 10-15
needed, ASP-700,
and shale stab.
14,750-15,900. LSND w/weight as 9.5-12.0 40-48 5-10
needed, ASP-700,
shale stab, and 3% KCL
Sufficient mud material to maintain mud properties, control lost
circulation and prevent a blowout will be available at the wellsite.
1P3/969-3
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6. Evaluation Process
Logs: DIL/SFL/CNL Total Depth to 11,000'
FDC-GR/Sonic-BHC Total Depth to 11,000'
DST's: None
Cores: • 2-60 foot cores in Dakota
Evaluation process may change at the discretion of the wellsite
geologist with the approval of the BLM.
Stimulation: No stimulation or frac treatment has been
formulated for this test. The BLM will be
notified by "Sundry Notice" prior to any
completion activity with a complete frac program.
The drillsite as approved, will be of sufficient
size to accommodate all completion activity.
7- Abnormal Conditions
No abnormal temperatures or pressures are anticipated. No H?S has
been reported or known to exist from previous drilling in the area
to this depth. Maximum anticipated bottom hole pressure is 6836 psi,
8. Drilling Activity and Auxiliary Equipment
A. Drilling Activity
Anticipated Commencement Date: July 1, 1986
Drilling Days: Approximately 110 days
Completion Days: Approximately 30 days
B. Auxiliary Equipment
1) A Kelley Cock will be kept in string at all times.
2) Periodic checks will be made each tour of the mud system.
3) A Stabbing Valve will be kept on the derrick floor to be
stabbed into the drill string whenever the Kelley is not in
the string.
4) No float will be used in the drill string.
1P3/969 - 4
C-1208
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•• T TT/-VTTV DTTCH FED. B
COMPANY SUN EXPLORATION & PROD. WELL NAME LUCKfcX uj.iu .
LOCATION.
INTERVAL TO BE USED
NW N'E SECTION 19 T12N R114W
""
500' to 15,900' TD
ANNULAR BOP
PIPE RAMS
13 5/8" 5000 W.E.
13 5/8" 10.000 W.P.f
BLIND RAMS 13 5/8" 1Q'000 W'P'
GATE VALVE 4~ 10.000 W.P.
CHECK VALVE 4" 10,000. W.PT
13 5/8" 10,000 W.P.
PIPE RAMS
GATE VALVE 2" 5.000 W.P.
13 5/8" 5,000 W.P.
CASING HEAD
•B.O.P .
J~} MANUAL
P^l HYDRAULIC
TRIM
^ 4" 10,000 W.P.
GATE. VALVE
4" 10,000 :•: §CR. VALVE
2" 5,000 W.P. GATE VALVE
13 3/8"
CASING SIZ
TEST PROCEDURE
1) Ram type preventers will be., tested to rated working pressure of stack o
70Z of internal yeild of casing whichever is less.
2) Annular type -preventers will be tested to 50% of rated working pressure
3) BOP will be tested at time of 'installation and at least every 30 days.
Pipe rams will be operated once each 24 hours and blind rams will be
tested on trips.
BOP PROCEDURES AND DRILLS
1) Approved close in procedure to be posted on the rig floor.
2) Each rig crew to hold a close in drill weekly.
3) Drills will be noted on IADC daily drilling report at the rig.
C-1209
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EXHIBIT .V2-
AUXILLIARY BOP EQUIPMENT '
1) Upper and'lower kelly valve (in use)
2) Safety valve (rig floor)
3) Inside BOP valve (rig floor) .
A) Extra drill pipe to drill collar sub (rig floor)
CHOKE MANIFOLD ' -
All valves and fittings will be rated at
working pressure.
manual operated choke
J TO HUO/GiS SEPARATOR
* ANO/OR PIT
-REUOTEUr OPERATED
CHOKE '
TO HUO/GiS
- -> SEPARATOR
* AMD/OR Pll
AHO/OH PIT
HOMNAI.
' F1G.3JL3.
TYPICAL CHOKE MANIFOLD ASSEMULY FOB 10M AKD ISM '
tUVTEO WORKING PBES.SURE SEHVICE - SURrACE IN-
STALLAT1UN
BOP ACTUATING SYSTEM • ' -
1) Accumulator capacity will supply 1*5 times volume necessary to close all
BOP equipment units with a minimum pressure of 203 psi above pre-charge
pressure.
2) Accumlator back up system supplied by a secondary power source independent
of primary power source, will be provided with sufficient capacity to close
all blowout preventers.
3) Locking devices will be provided on ram type preventers.
A) Primary BOP actuating control will be hydraulic and located either in the
dog house or on the rig floor. Back-up control will be provided by hand-
wheel manual operation .of BOP -. _
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