2009 Drilling, Redrilling, Well Abandonment, and Well Pad ...

2009 Drilling, Redrilling, Well 

Abandonment, and Well Pad 

Restoration Plan 

Inglewood Oil Field 

Baldwin Hills CSD Conditions 

L.16; E.26.c 

Prepared for: 

Approved 

January 2009 

Revised – June 2009 

Revised – July 2009 

Prepared by: 

Plains Exploration & Production Co. Arup 

5640 South Fairfax Avenue 12777 West Jefferson Boulevard 

Telephone Rd., Suite 203 Suite 200 

Los Angeles, CA 90056 Los Angeles, CA 90066

Plains Exploration & Production Company (PXP) 

2009 Drilling Plan--Inglewood Oil Field 

Baldwin Hills Community Standards District 

 

1 Introduction 1 

2 2009 Plan 3 

2.1 Plan Overview 3 

2.2 CSD Plan Requirements 4 

i. The Maximum Number of Wells Proposed to be Drilled or Redrilled 4 

ii. Approximate Location of All Wells Proposed to be Drilled or Redrilled 6 

iii. Approximate Location of All New Well Pads, Including Size and Dimensions 8 

iv. Estimated Target Depth of All Proposed Wells and Their Estimated Bottom Hole Locations 9 

v. A Discussion of the Steps That Have Been Taken to Maximize Use of Existing Wells Pads, 

Maximize Use of Redrilled Wells, and Maximize the Consolidation of Wells 10 

vi. Location of All Proposed Well Abandonments, if Known, in Accordance with DOGGR 

Integrity Testing Program of Idle Wells 14 

vii. Location of All Well Pads Proposed to be Abandoned and Restored 15 

viii. A Proposed Schedule and Phasing of the Drilling, Redrilling, Well Abandonment, Well Pad 

Abandonment and Restoration Activities 16 

ix. A Discussion of the Latest Equipment and Techniques that are Proposed for Use as Part of 

the Drilling and Redrilling Program to Reduce Environmental Impacts 17 

x. A Topographic Vertical Profile Showing Proposed Location of New Wells that Reflects Local 

Terrain Conditions and that Addresses the Potential Visibility of Existing and Proposed Well 

and Other Production Facilities from Residential and Recreation Areas 19 

 

Schedule 1—2009 Proposed Drilling and Redrilling Schedule 5 

 

Table 1 - 2009 Proposed Drilling and Redrilling Location Table 7 

Table 2—Size and Dimensions of Proposed New Well Pads 9 

Table 3 – Offset Idle Wells within 150’-300’ of 2009 Proposed Well Locations 12 

Table 4 - 2009 Proposed Well Abandonment Locations 15 

 

1. 2009 Drilling, Re-Drilling, and Well Abandonment Plan – Location Map 

2. Production Well Potential Visibility: TVIC- 181 Drawing No. EA-VS-002 





7. Production Well Potential Visibility: TVIC-VIC1-1 Drawing No. EA-VS-007 

8. Production Well Potential Visibility: TVIC-VIC-340 Drawing No. EA-VS-008 

9. Production Well Potential Visibility: TVIC-VIC-401 Drawing No. EA-VS-009 

10. Production Well Potential Visibility: VIC2-160 Drawing No. EA-VS-010 

11. Production Well Potential Visibility: VRU-143 RD 1 Drawing No. EA-VS-011 

12. Production Well Potential Visibility: VRU-363 Drawing No. EA-VS-012 



15. Production Well Potential Visibility: BC - 285 Drawing No. EA-VS-015 

16. Production Well Potential Visibility: BC - 702 Drawing No. EA-VS-016 

17. Production Well Potential Visibility: LAI1-455 Drawing No. EA-VS-017 



20. Production Well Potential Visibility: BC-LAI1-465 Drawing No. EA-VS-020 






Approved 

Page i / 20 July 2009





27. Production Well Potential Visibility: LAI1-STK-BC-408 Drawing No. EA-VS-027 

28. Production Well Potential Visibility: STK-460 Drawing No. EA-VS-028 

29. Production Well Potential Visibility: STK-461 Drawing No. EA-VS-029 

30. Production Well Potential Visibility: VIC1-390 Drawing No. EA-VS-030 

31. Visual Impact Photograph Location: 2A 

32. Visual Impact Photograph Location: 3C 

33. Visual Impact Photograph Location: 6C 

34. Visual Impact Photograph Location: 7B 

35. Visual Impact Photograph Location: 8A 

36. Visual Impact Photograph Location: 8B 

Approved 

Page ii / 20 July 2009




 

The Baldwin Hills Community Standards District (CSD) was adopted by the Los 

Angeles Planning Department on October 28, 2008 and became effective on 

November 28, 2008. The CSD governs operations on the Baldwin Hills Oil Field 

(a.k.a. Inglewood Oil Field), located in the Baldwin Hills District. The field is 

currently operated by Plains Exploration & Production Company (PXP). The goal 

of the CSD is to ensure that oil field operations are conducted in a safe manner and 

are compatible with the surrounding uses. 

The CSD requires that a Drilling, Redrilling, Well Abandonment, and Well Pad 

Restoration Plan (hereinafter referred to as the Plan or the 2009 Plan or the 2009 

Drilling Plan) be provided to the County of Los Angeles within 60 days following the 

effective date of the CSD, or at such later date as may be approved by the director 

for good cause shown. Specifically, section E.26.c. of the CSD states the 

following: 

Drilling, Redrilling, and Reworking Operations. The operator shall comply with all of 

the following provisions: 

c. Annual Drilling, Redrilling, Well Abandonment, and Well Pad Restoration 

Plan. Before the end of each calendar year, the operator shall develop and deliver 

to the director an annual drilling, redrilling, well abandonment, and well pad 

restoration plan that shall describe all drilling, redrilling, well abandonment, and well 

pad restoration activities that may be conducted during the upcoming calendar 

year. Drilling and redrilling shall be scheduled to avoid over concentration of such 

activities in that year in any one area if located near a developed area. The 

operator may at any time submit to the director proposed amendments to the then 

current annual plan. No drilling, redrilling, or abandonment activity may be 

commenced unless it is described in a current annual plan (or amendment thereto) 

which has been approved by the director. The annual plan (and any amendments) 

shall be provided to the CAP for review and comment. All comments on the annual 

plan from the CAP shall be submitted to the director in writing, and, if timely 

submitted, will be considered as part of the director’s review and approval. The 

director shall complete the review of the annual plan (and any amendments) within 

45 days of receipt, and shall either approve the annual plan or provide the operator 

with a list of deficiencies. The annual plan shall comply with the provisions of this 

subsection, and shall include the following: 

i. The maximum number of wells proposed to be drilled or redrilled; 

ii. 

iii. 

iv. 

Approved 

Approximate location of all wells proposed to be drilled or redrilled; 

Approximate location of all proposed new well pads, including their size 

and dimensions; 

Estimated target depth of all proposed wells and their estimated bottom 

hole locations; 

v. A discussion of the steps that have been taken to maximize use of 

existing well pads, maximize use of redrilled wells, and maximize the 

consolidation of wells; 

Page 1 / 20 July 2009




vi. 

vii. 

viii. 

ix. 

Location of all proposed well abandonments, if known, in accordance 

with DOGGR integrity testing program of idle wells; 

Location of all well pads proposed to be abandoned and restored; 

A proposed schedule and phasing of the drilling, redrilling, well 

abandonment, well pad abandonment, and restoration activities; 

A discussion of the latest equipment and techniques that are proposed 

for use as part of the drilling and redrilling program to reduce 

environmental impacts; and 

x. A topographic vertical profile showing proposed location of new wells 

that reflects local terrain conditions and that addresses the potential 

visibility of existing and proposed well and other production facilities from 

residential and recreation areas. 

Approved 





 

 

 

The Plan covers activities for the 2009 calendar year. Drilling and redrilling activities 

will conform to the setback requirements contained in the CSD, Section E.2.n as 

follows: 

Drilling and Redrilling Setbacks: The following setbacks shall apply within the oil field 

for drilling and redrilling: 

i. At least 400 feet from developed areas 

ii. At least 20 feet from any public roadway 

Developed areas are defined in the CSD as “Any lot or parcel of land containing any 

residential, commercial, industrial, or office structure, or used for residential, 

commercial, industrial, or office purposes (provided that no lot or parcel of land on the 

oil field shall be considered to be developed area solely because of the presence 

thereon of the Cone Trust House or of a structure used by any operator for 

administrative functions associated with the oil field); or any lot or parcel of land 

containing any public park, house of worship, cemetery, school, parking lot, or any 

recreation area which has been developed and opened for public use.” 

Two types of wells are drilled in the oil field; injection and production wells. Injection 

wells are used to pump fluids into the oil bearing geologic formation at depth, forcing 

the oily water in the formation to migrate to nearby production wells for recovery. 

Wells are drilled by erecting temporary well derricks, or drilling rigs and related 

components, and drilling to total depth. The well is drilled and completed in 

accordance to regulated conditions specified by the Division of Oil and Gas and 

Geothermal Resources (DOGGR). The geologic formation of interest for PXP’s 2009 

drilling program lies at an approximate subsurface depth of between 1,000 feet and 

4,100 feet. Similar wells typically take approximately 13 days to drill and complete, 

including mobilization and demobilization of drilling equipment. 

Based on the uncertainty that any given well will perform as anticipated, PXP 

prepared a plan as discussed in the sections that follow. 

A drilling (and redrilling) schedule was developed utilizing two drilling rigs on the field 

simultaneously for the 2009 Plan year. The CSD allows for a maximum of 3 drilling 

rigs on the field at any one time. 

Approved 

Planned activities of well abandonment and well pad abandonment and restoration 

are also listed below and will begin upon approval by the Director. 





 

! 

i. The Maximum Number of Wells Proposed to be Drilled or 

Redrilled 

During the 2009 Plan year the CSD allows for a maximum of 24 wells to be drilled or 

redrilled. PXP currently proposes to drill the 24 locations as shown on Attachment 1, 

Location Map. 16 additional alternative locations are also shown on Attachment 1. 

Schedule 1 represents the conceptual 2009 drilling schedule based on the use of 2 

drilling rigs, with drilling scheduled to commence approximately on August 15, 2009. 

Though the locations and respective schedule reflect geologic targets based on the 

best geologic and reservoir data available, new well performance data, economic 

conditions, company plans and reallocation of budgets may significantly alter the 

schedule and number of wells drilled in 2009 (not to exceed 24 wells). 

Prior to drilling or redrilling of all wells (up to 24 in 2009), PXP will prepare and submit 

Notices of Intent to drill (NOI) to DOGGR for the procurement of the respective 

drilling or redrilling permits. PXP will also prepare and formally submit the respective 

Site Plan Review Applications for the wells to the Los Angeles County Planning 

Department for review and approval. PXP will not commence drilling or redrilling 

activities for any well until respective well approvals from both DOGGR and Los 

Angeles County Planning are obtained. 

The CSD allows for a maximum of 600 wells to be drilled or redrilled over the next 20 

years. PXP will include a cumulative summary of wells drilled and redrilled in prior 

Plan periods commencing with the 2010 Plan. 

Approved 


Plains Exploration & Production Company (PXP) Baldwin Hills Community Standards District 


Approved 





ii. Approximate Location of All Wells Proposed to be Drilled or 

Redrilled 

Table 1 below provides X - Y coordinates for the 24 well locations and 16 alternate 

locations, including bottom hole and surface locations. A maximum of 24 wells will 

be drilled in the 2009 Plan year. Rectangles drawn to scale on the Attachment 1 

location map represent the footprints (12’ X 45’) of conventional surface pumps and 

identify the 19 potential surface location candidates projected to be completed as 

producing wells. Squares drawn to scale on Attachment 1 represent the footprint (12’ 

X 12’) of conventional injection wells and indicate the surface locations of five wells 

proposed to be completed as injectors. The acronym “RD” within a well name 

reflects a well to be redrilled. 

Geography, duration of drilling activities and proximity to developed areas were the 

criteria used for considering which wells needed to be examined to avoid 

overconcentration of drilling activities. Duration of drilling activities include the 

mobilization of drilling rig equipment, actual drilling operations and demobilization of 

drilling equipment. The preceding Schedule 1, 2009 Proposed Drilling and Redrilling 

Schedule, sets forth the duration of drilling activity per individual well. 

Based on the well locations for the 2009 Drilling Plan, the developed areas that were 

reviewed for overconcentration of drilling activities focused on Windsor Hills, Ladera 

Heights, Blair Hills, Raintree Apartments, Culver Crest and West LA College. Based 

on the aforementioned criteria, four wells in the area of Windsor Hills, including Well 

Numbers 7, 8, 9 and 20, STK-460, LAI1-STK-BC-408, BC-702, and STK-461 

respectively, were identified for further review to ensure scheduling would avoid 

overconcentration of drilling activity in this area. Only 1 well of potential concern, 

Number 19, LAI1-459, will be drilled in proximity to Ladera Heights and 1 well, 

Number 24, VRU 365, will be drilled in proximity to Blair Hills. No wells of potential 

concern will be drilled in proximity to Raintree Apartments, Culver Crest or West LA 

College. Since there is only one well each scheduled for Ladera Heights and Blair 

Hills, scheduling of these wells is not a concern. The estimated duration for drilling 

activity for each of these wells is approximately 10-11 days. 

After careful examination of the four locations near Windsor Hills, a schedule has 

been developed that would avoid overconcentration of drilling activities in this area. 

The schedule calls for drilling two of the wells (well number 7, STK-460 and Well 

Number 8, LAI1-STK-BC-408) in succession. Total duration of drilling activity for 

these two wells is anticipated to last approximately 3 weeks. Both of these well are 

located near the northern end of Windsor Hills. Once these two wells are complete, 

the drilling rig will then be mobilized for a period of approximately 6-7 weeks to drill 

wells located in other areas away from Windsor Hills. The rig will return to locations 

near Windsor Hills to drill Well Numbers 9, BC-702, and Number 20, STK-461, in 

succession, a total drilling activity period of approximately 3 weeks. Well BC-702 is 

located north of Windsor Hills near Stoker Street, and well STK-461 is located near 

the middle of Windsor Hills. No other wells of potential overconcentration concern 

are scheduled for drilling in proximity to Windsor Hills during the 2009 Plan year. 

Approved 





"#$ $% 

2009 PXP Drilling and Redrilling Proposed Locations 

Well 

Number 

1 

2 

3 

4 

5 

6 

Bottom Hole Locations 

Surface Locations 

Well Name TYPE X (Easting) Y (Northing) x(Easting) Y(Northing) 

VRU-363 

LAI1-473 

LAI1-466 

9 

10 BC-285 

11 

12 

Producer 

Producer 

Producer 

Producer 

Injector 

Injector 

Estimated 

Total 

Vertical 

Depth @ 

Target 

Depth 

4,173,680.00 4,115,894.00 4,173,719.00 4,115,757.00 3613 

4,175,527.00 4,113,582.00 4,175,763.00 4,113,423.00 3566 

4,176,535.00 4,113,015.00 4,176,743.00 4,112,832.00 3742 

4,176,230.00 4,112,775.00 4,176,447.00 4,112,688.00 3737 

4,176,616.00 4,112,858.00 4,176,823.00 4,112,723.00 3432 

4,173,930.00 4,114,628.00 4,173,857.57 4,114,707.09 3662 

Producer 4,178,634.00 4,110,332.00 

Producer 4,178,445.00 4,110,810.00 

BC-702 Producer 4,178,265.00 4,111,180.00 

Producer 4,177,960.00 4,112,176.00 

TVIC-VIC1-1 Producer 4,172,540.00 4,115,815.00 

VRU-143 

RD 1 

13 LAI1-456 

14 

15 LAI1-455 

16 

17 

18 

19 LAI1-459 

20 STK-461 

21 

22 

23 

24 

Redrill 

Prod 

4,174,012.00 4,116,115.00 

Producer 4,178,260.00 4,110,475.00 

VIC1-401 Producer 4,173,755.00 4,114,210.00 

Producer 4,177,650.00 4,111,070.00 

LAI1-472 Producer 4,174,157.00 

TVIC-181 Producer 4,172,258.00 

TVIC-221 Producer 4,171,970.00 4,115,915.00 

Producer 4,176,130.00 4,111,990.00 

Producer 4,178,564.00 4,109,795.00 

TVIC-275 Producer 4,171,670.00 

LAI1-469 Injector 4,175,110.00 

BC-LAI1- 

465 

BC-LAI1- 

474 

VIC1-VRU- 

LAI1-900 

7 STK-460 

LAI1-STK- 

8 BC-408 

BC-LAI1- 

801 

4,178,493.00 4,110,300.00 3454 

4,178,469.00 4,110,838.00 3388 

4,178,235.00 4,111,315.00 3437 

4,177,721.70 4,112,003.96 3527 

4,172,655.00 4,115,846.00 3740 

4,174,015.00 4,116,028.00 3601 

4,178,004.00 4,110,583.00 3332 

4,173,796.00 4,114,244.00 3798 

Approved 

Injector 4,176,670.00 

VRU-365 Injector 4,173,680.00 

4,177,470.00 4,111,185.00 3309 

4,114,083.00 4,174,315.00 4,113,869.00 3721 

4,116,660.00 4,172,113.00 4,116,772.00 3886 

4,171,990.52 4,116,163.89 3822 

4,176,205.83 4,112,053.15 4066 

4,178,642.00 4,109,775.00 3592 

4,116,410.00 4,171,702.00 4,116,399.00 3837 

4,113,935.00 4,175,263.00 4,113,925.00 3542 

4,112,520.00 4,176,789.00 4,112,770.00 3721 

4,116,680.00 4,173,706.00 4,116,501.00 3847 







Number 

A1 

A2 

A3 

A4 

A5 

A6 

A7 

A8 

A9 

A10 

A11 

A12 

A13 

A14 

A15 

A16 

Bottom Hole Locations 


Well Name TYPE X (Easting) Y (Northing) x(Easting) Y(Northing) 

Injector 

Redrill Inj 4,173,685.00 

TVIC-274 Producer 4,172,315.00 

LAI1-470 Producer 4,174,830.00 

LAI1-471 Producer 4,174,280.00 

VRU-366 Producer 4,174,460.00 

Producer 4,173,108.00 

VIC1-340 Producer 4,173,395.00 

VRU-367 Producer 4,174,758.00 

LAI1-467 Producer 4,175,335.00 

VIC2-160 Producer 4,171,250.00 

LAI1-462 

VIC1-VRU- 

214 RD 1 

VRU-TVIC- 

248 

VIC1-390 

VRU-LAI1- 

211 RD 1 

Producer 4,173,820.00 

Redrill Inj 4,175,195.00 

BC-703 Injector 4,179,085.00 

LAI1-468 Injector 4,175,050.00 

VRU-364 Injector 4,173,906.00 

Estimated 

Total 

Vertical 

Depth @ 

Target 

Depth 

4,175,600.00 4,112,340.00 4,175,355.25 4,112,013.71 4054 

4,115,230.00 4,173,639.00 4,115,245.00 3598 

4,115,770.00 4,172,445.00 4,115,778.00 3787 

4,114,395.00 4,174,735.00 4,114,537.00 3436 

4,114,325.00 4,174,209.00 4,114,464.00 3587 

4,114,785.00 4,174,623.00 4,114,675.00 3399 

4,116,348.00 4,173,238.00 4,116,079.00 3742 

4,115,015.00 4,173,294.00 4,114,973.00 3712 

4,115,516.00 4,174,616.00 4,115,446.00 3421 

4,113,000.00 4,175,143.00 4,113,086.00 3782 

4,116,465.00 4,171,457.00 4,116,454.00 3870 

4,113,830.00 4,173,971.14 4,113,855.08 3906 

4,114,537.00 4,175,208.00 4,114,638.00 3448 

4,111,390.00 4,178,692.00 4,111,591.00 3721 

4,112,648.00 4,174,990.00 4,112,586.00 4049 

4,115,002.00 4,174,107.00 4,114,982.00 3541 

Approved 

Coordinates in feet, NAD 1927, CA Plane, Zone 7; Depth in feet 

iii. Approximate Location of All New Well Pads, Including Size 

and Dimensions 

The location map (Attachment 1) illustrates the locations of new drilling pads 

proposed for 2009 wells, including 16 alternate locations. If a surface location for a 

well (either a producer on an injector) is not shown as located on a new well pad, 

said surface location will be constructed on an existing pad. 

A pad required for drilling a new well is typically 110’ X 235’. After completion of the 

well, production well pumping units require an area 45’ X 12’ and injection wells 

require an area of 12’ X 12’. 





One proposed new drilling pad for the 2009 Plan will be larger than the typical pad as 

it will accommodate three wells. The size of the pad is smaller for the collective three 

wells than the same drilled and located individually. Please see Attachment 1 and 

Table 2 for location, size and dimensions of new well pads. 

Construction of well pads is performed under PXP’s annual Master Grading Plan or 

under a Site Specific Grading Permit issued by LA County Public Works Department. 

The Master Grading Plan, when prepared, and the Site Specific Grading Permit are 

prepared and stamped by a registered professional engineer and a California 

certified engineering geologist, and approved by the Los Angeles County Director of 

Public Works. PXP conducts all grading throughout the oil field in accordance with 

these requirements. A paleontological monitor will be present for well pad grading if 

the proposed grading occurs in paleontologically sensitive sediment areas. 

Table 2 below identifies the size and dimensions for each of the proposed well pads. 

&' (# 

#)* )* 

Size and Dimensions of Proposed New Well Pads 

2009 Plan - Well Name Drilling Pad Dimensions Square Feet 

LAI-473 100’ X 235’ 23,500 

* BC-LAI1-465 * 250’ X 235’ * 58,750 

* BC LAI1-474 * 250’ X 235’ * 58,750 

LAI1-455 100’ X 235’ 23,500 

* BC-LAI1-801 * 250’ X 235’ * 58,750 

* = Wells share 1 common pad 

(alternate well and location) 

LAI-462 100’ X 235’ 23,500 

Approved 





iv. Estimated Target Depth of All Proposed Wells and Their 

Estimated Bottom Hole Locations 

Estimated bottom hole locations for the 24, 2009 Plan wells are demarked on the 

location map, Attachment 1. Estimated bottom hole locations for the 16 alternate 

locations are also demarked on the location map, Attachment 1. Approximate target 

depths for all wells are noted on Table 1. 

Approved 





v. A Discussion of the Steps That Have Been Taken to Maximize 

Use of Existing Wells Pads, Maximize Use of Redrilled Wells, 

and Maximize the Consolidation of Wells 

To maximize the use of existing pads, PXP surveyed surface locations for all 

geologic target (bottom hole) locations. PXP then projected a maximum horizontal 

reach radius from each target location to an available and suitable surface location 

that would support respective facilities for the type of well proposed (production or 

injection). PXP prioritized the use of available existing pads to the maximum degree 

possible. 

Of the 24 proposed well locations for the 2009 Plan, including the 16 alternate 

locations, only six wells may require new drilling pads. Please refer to Attachment 1 

map and Table 2 for location and dimensions of all new well pads. 

Idle wells were utilized by PXP for new wells whenever possible (redrills). Redrills 

preclude the need for new pad grading and construction locations. Table 3 identifies 

all idle wells evaluated for redrilling use and the respective criteria that disallowed 

use of said idle wells for redrilling. 

The criteria to be evaluated in order to determine the viability of utilizing an idle well 

for redrilling are as follows: 

1. The ability to maximize well surface location consolidation is constrained by the 

shallow depth of the wells to be drilled or redrilled in 2009. Geologic formation well 

target depths for the 2009 Plan range between 1,000 feet and 4,100 feet. This range 

of depths allows for a maximum horizontal drilling displacement ranging between 150 

and 300 feet (from the surface location) for both producers and injectors. The kick off 

point (KOP) must lie within the 150-300 feet of the surface location for considered 

use of an idle well. The KOP is the point as to which drilling of the new borehole 

(from the existing idle well) must commence. The borehole must achieve vertical 

orientation as to the formation to be perforated for both injectors and producers. The 

section to be perforated must observe the same X and Y coordinates as the 

respective bottom hole location listed on Table 1; 

2. DOGGR 2007 Field Rules for Inglewood require that the production casing be 

cemented back to surface. For a producing well, the required casing in the 

perforated section must be 9 5/8”, with a corresponding 13 3/8” casing at surface. 

For a redrill injector, the minimum production casing size at the injection interval is 7” 

with a corresponding casing size at surface of 9 5/8”; 

3. The existing inclination and deviation direction of the idle well is also a factor. 

Should the idle well be deviated away from the top target, it may be impossible to 

directionally drill to the proposed target; 

4. The redrill candidate must have excellent casing integrity; the casing cannot be 

damaged; 

5. The use of an idle well can trigger an offset well obligation per the provisions of 

an adjacent lease, prompting the drilling and completion of an additional well where 

one well would achieve maximum production efficiency; 

6. In various cases, it is much less expensive to drill a new well rather than redrill an 

existing idle well; the risk of mechanical problems and respective extensive 

expenditures may increase dramatically when the directional drilling angle is 

exceedingly high. This could also prompt the location of a drilling operation to be 

extended; 

7. Subsurface avoidance with other existing wells (including idle, producing or 

injection wells) must be considered for all wells, including redrills. 

Approved 






Number 

There are three (3) wells in the 2009 Plan which have met the criteria and can be 

redrilled. All proposed surface well locations were consolidated to the maximum 

extent possible. 

+,( 

((* (* - 

-."+ 

+.( 

( 

#* % 

2009 PXP Offset Idle Wells within 300 feet of Drilling and Redrilling Proposed Locations 

Possible 

Offset Idle 

Proposed Well Type 

Redrill 

Comments 

Well(s) 

Candidate? 

VIC-VRU-LAI1- 

207A 

Yes No 

1 VRU-363 Producer N/A 

2 LAI1-473 Producer LAI1-340 N 9 5/8" casing diameter too small 

3 BC-LAI1-465 Producer N/A 

4 LAI1-466 Producer N/A 

5 BC-LAI1-474 Injector N/A 

VIC1-35 N 8 5/8" casing diameter too small 

VRU-LAI1-206 

N 

Unable to reach top target with KOP at 

550'MD in 9 5/8" casing 

Previous redrill candidate. Top of 

cement between the 7” and 9 5/8” 

6 

casing precludes a cut and recover 

VIC1-VRU-LAI1- 

Injector 

operation prior to milling a window in 

900 

the 9 5/8” casing. 

7 STK-460 Producer 

8 LAI1-STK-BC-408 Producer 

N 



LAI1-1044 

N 

BRADNA-COM-2 N 9 5/8" casing diameter too small 


LAI-COMM-BC- 

1RD N 10 3/4" casing diameter too small 



STK-301 

N 

STK-LAI1-302 N 9" casing diameter too small 

STK-38B N 7" casing diameter too small 

STK-BC-LAI1-21 N 7" casing diameter too small 

LAI-STK-BC- 

3RD2 N 7" casing diameter too small 

LAI-STK-BC-4 N 7" casing diameter too small 

Approved 

LAI-COMM1-1RD N 9 5/8" casing diameter too small 

BC-50RD N 10 3/4" casing diameter too small 

BC-351 

N 

Holding for Investment Zone 

recompletion 

9 BC-702 Producer BC-404 N 10 3/4" casing diameter too small 

BC-442 N 8 5/8" casing diameter too small 

BC-551A N 9 5/8" casing diameter too small 

BC-901 N 9 5/8" casing diameter too small 

13 3/8" casing shoe too shallow at 400', 

10 BC-285 Producer BC-332 N 

need 13 3/8" at minimum 500'depth 

11 TVIC-VIC1-1 Producer TVIC-58 N 8 5/8" casing diameter too small 






Number 


Possible 

Offset Idle 


Redrill 

Comments 




VIC1-102 N 7" casing diameter too small 

12 VRU-143 RD 1 

Redrill 

Producer VRU-143 

Y 



13 LAI1-456 Producer 

LAI-COMM-BC- 

1RD N 10 3/4" casing diameter too small 

STK-LAI1-302 N 9" casing diameter too small 

LAI1-287 N 7" casing diameter too small 


14 VIC1-401 Producer VIC1-125 N 10 3/4" casing diameter too small 

WRZU-382 N 8 5/8" casing diameter too small 



17 TVIC-181 Producer TVIC-57 

N 

Severe dog-leg of 11 degrees at a 

depth of 320’ precludes use 

TVIC-213 N 7" casing diameter too small 

18 TVIC-221 Producer TVIC-43A N 11 3/4" casing diameter too small 

19 LAI1-459 

Producer 

13 3/8" casing shoe too shallow at 498', 

LAI1-187 

N need 13 3/8" at minimum 500'depth 

20 STK-461 Producer STK-LAI1-302 N 9" casing diameter too small 

21 TVIC-275 Producer TVIC-49 N 8 5/8" casing diameter too small 

22 LAI1-469 Injector LAI1-318 

23 BC-LAI1-801 Injector N/A 

24 VRU-365 Injector N/A 

Mechanical integrity investigation under 

evaluation. 



LAI1-101A 

N 

7" casing cemented inside 9 5/8" 

A1 LAI1-462 Injector LAI1-313 

N casing 


LAI1-315A 

N 550'MD in 9 5/8" casing 

VIC1-VRU-214 RD Redrill 

A2 

1 Injector VIC1-VRU-214 Y 

A3 TVIC-274 Producer TVIC-58 N 8 5/8" casing diameter too small 

A4 LAI1-470 Producer VRU-LAI1-204 N 9 5/8" casing diameter too small 


A5 LAI1-471 Producer LAI1-1044 N 9 5/8" casing diameter too small 

VRU-LAI1-206 N 9 5/8" casing diameter too small 

VRU-166 N 8 5/8" casing diameter too small 

A6 VRU-366 Producer WRZU-311 N 8 5/8" casing diameter too small 

Approved 

VRU-LAI1-205 N 9 5/8" casing diameter too small 

A7 VRU-TVIC-248 Producer TVIC-260RD N 9" casing diameter too small 

VIC1-118A N 7" casing diameter too small 

A8 VIC1-340 Producer VIC1-120 N 7" casing diameter too small 

WRZU-381 N 11 3/4" casing diameter too small 






Possible 


Offset Idle 


Redrill 

Number 



Comments 

A9 VRU-367 Producer RUBEL 30 N 12 3/4" casing diameter too small 

A10 LAI1-467 Producer N/A 

VIC2-12 N 7" casing diameter too small 

A11 VIC2-160 Producer VIC2-14A N 7" casing diameter too small 


A12 VIC1-390 Producer N/A 

VRU-LAI1-211 RD Redrill 

A13 

1 Injector VRU-LAI1-211 Y 



A14 BC-703 Injector BC-172A N 


A15 LAI1-468 Injector 

LAI1-424 

N 





A16 VRU-364 Injector VRU-162 N 

Definitions: 

KOP: Kick off Point, depth that redrill starts in existing wellbore; N/A: No wells available for consideration within a 

300’ radius of the bottom hole location 

 

Approved 





vi. Location of All Proposed Well Abandonments, if Known, in 

Accordance with DOGGR Integrity Testing Program of Idle 

Wells 

PXP currently has five eleven wells identified for plugging and abandonment in 2009. 

Please see Attachment 1, Location Map, and Table 4 for identification of wells and 

respective locations. More candidates for plugging and abandonment may arise as 

deemed appropriate by DOGGR and PXP throughout 2009. 

Well abandonment is defined as the permanent plugging of a well, in accordance 

with state law as set forth in Division 3, Chapter 1 of the California Public Resources 

Code and pursuant to requirements of DOGGR, found in Title 14 of the California 

Code of Regulations, sections 1723-1723.9, or in accordance with subsequently 

enacted applicable state laws or regulations regarding well abandonment. PXP 

conducts well testing and abandonment in accordance with these DOGGR 

requirements as well as those specified in the Public Resources Code section 

3206.5. 

In addition to plugging and abandonment requirements contained in the CSD, there 

are other factors that determine when wells will be abandoned. Oil field economics 

and crude oil and gas prices determine whether wells remain viable future candidates 

as either producers or injectors. Wells that are mechanically sound and pass idle 

well testing requirements retain potential for economic production or injection 

consideration. 

Additionally, in the course of day to day well operations, economically prohibitive 

repair options for mechanical problems encountered on marginally productive wells 

may also dictate plugging and abandonment. 

PXP will include a cumulative summary of wells plugged and abandoned in prior Plan 

periods commencing with the 2010 Plan. 

/"#* #* % 



Well Name TYPE x (East) Y (North) 

LAI1-101A Oil 4,175,753.55 4,112,494.73 

LAI1-250 Oil 4,176,455.38 4,111,503.82 

VIC2-20 Oil 4,170,919.74 4,116,259.40 

WRZU-311 Oil 4,174,705.43 4,114,901.78 

WRZU-353 Oil 4,175,731.73 4,113,960.31 

BC-341 Oil 4,177,788.00 4,111,518.00 

TVIC-49 Oil 4,171,701.00 4,116,510.00 

TVIC-204 Water Injector 4,171,677.00 4,115,684.00 

VIC1-83 Oil 4,172,476.00 4,110,868.00 

LAI1-COMM1-1 Oil 4,178,320.00 4,110,868.00 

VIC1-LAI1-2 Water Injector 4,174,562.00 4,112,481.00 

Approved 





vii. Location of All Well Pads Proposed to be Abandoned and 

Restored 

At the time of submittal, there are no well pads identified as part of the 2009 Plan to 

be abandoned and restored. To minimize economic expenditure and soil 

disturbance, PXP’s standard practice is to consolidate new wells onto existing pads 

whenever possible. The cost of developing new pads is very high and future reuse is 

always a consideration, thus the reason that well pads are not regularly restored. 

This practice also yields less impact to existing undisturbed areas. In addition, due to 

climatic conditions and respective concern toward fire safety, PXP has endeavored to 

maintain buffer zones between equipment and trees and undergrowth. PXP will 

continue to evaluate well pads for restoration consideration. 

Approved 





viii. A Proposed Schedule and Phasing of the Drilling, Redrilling, 

Well Abandonment, Well Pad Abandonment and Restoration 

Activities 

The planned drilling and redrilling period for 2009 commences following the date of 

Plan approval (anticipated before August 15, 2009) through December 31, 2009. No 

well drilling or redrilling activities will commence until respective DOGGR permit 

application approvals have been obtained. Furthermore, no well drilling or redrilling 

activities will commence until respective Site Plan Review Application approvals have 

been obtained from the County of Los Angeles. Said Site Plan Review applications 

will evidence pre-approval of the 2009 Drilling Plan by County of Los Angeles and 

shall adhere to the provisions of the CSD. 

Well plugging and abandonment activities will occur over the course of the 2009 

calendar year after approval of the Plan by the Director and upon permit approval for 

plugging and abandonment from DOGGR and County of Los Angeles. 

To the maximum degree possible, PXP consolidated multiple wells to existing or new 

pads. PXP will also schedule drilling and redrilling activities to avoid over 

concentration of such activities in any one area if located near a developed area. 

This will be accomplished by rotating operational activities among the various Plan 

locations. Furthermore, based on the anticipated schedule for the 2009 Plan year, at 

no time during said year will there be more than two drilling or redrilling rigs in 

operation on the oil field at any given time. The CSD allows for a maximum of three 

drilling rigs at any one time. 

Drilling and Redrilling Activities 

Drilling and Redrilling Start Date: August 15, 2009 or date of Plan approval, 

whichever is later. Please see Schedule 1. 

Drilling and Redrilling End Date: December 31, 2009 

Average Period to Drill or Redrill a Well: 13 days 

Well Abandonment Activities 

Well Abandonment Start Date: Date of Plan approval 

Well Abandonment End Date: December 31, 2009 

Average Period for Well Abandonment: 1 week per well 

Maximum Number of Well Abandonments: Five (5) identified at time of Plan 

submittal. Additional well Abandonments may take place throughout the 2009 Plan 

year 

Approved 

Well Pad Abandonment and Restoration Activities 

Well Pad Abandonment and Restoration Activities Start Date: N/A 

Well Pad Abandonment and Restoration Activities End Date: N/A 

Estimated Period for Well Abandonment and Restoration Activities: N/A 

Maximum Number of Well Pad Abandonments and Restorations: None (0) identified 

for the 2009 Plan period 





ix. A Discussion of the Latest Equipment and Techniques that are 

Proposed for Use as Part of the Drilling and Redrilling 

Program to Reduce Environmental Impacts 

PXP utilizes technologies that minimize potential adverse affects of drilling and 

redrilling activities and maintains compliance with CSD requirements, and with state 

and federal regulations. 

Below is a list of the latest equipment and techniques that will be used as part of the 

drilling and redrilling program. 

1. A gas buster and portable flare, approved by the SCAQMD, shall be available for 

immediate use to remove any gas encountered during drilling operations from 

drilling mud being sent to the shaker table, and to redirect such gas to the 

portable flare for combustion. 

2. An odor suppressant spray system shall be used on the mud shaker tables for all 

drilling and redrilling operations to minimize any potential odors. 

3. All drilling and redrilling rigs shall utilize CARB/EPA Certified Tier II or better 

diesel engines to help reduce NOx emissions and heavy duty diesel catalysts to 

help reduce hydrocarbons and particulate matter. 

4. All off-road diesel construction equipment engines shall utilize Tier III or better 

diesel engines plus Level 3 CARB verified diesel catalysts during times when 

drilling and drill pad construction are occurring simultaneously. This is designed 

to reduce NOx, hydrocarbon and particulate matter emissions. 

5. The following setbacks shall apply within the oil field for drilling and redrilling 

activities: 

a. At least 400 feet from developed areas 

b. At least 20 feet from any public road 

6. All drilling and redrilling in the oil field between the hours of 6:00pm and 8:00am 

shall be conducted in conformity with the Quiet Mode Drilling Plan. The Quiet 

Mode Drilling Plan is intended to minimize potential noise impacts and includes 

the following mitigation measures: 

Approved 

a. Cover V-door with rubber matting, and ensure the rubber matting stays on 

when handling pipe. 

b. Cover rig floor with rubber matting or wood. 

c. Place rubber matting or wood on the pipe racks and catwalk when rolling 

pipe off the pipe racks onto the catwalk. 

d. Use hydraulic tongs, instead of chain or pneumatic tongs. 

e. Wrap hammer wrenches with rags. 

f. Install sound barrier on the derrick at the “monkey board”. 

g. Install soundproofing blankets around draw-works, rig floor, mud pumps and 

substructure. 

h. Install sound wall at the perimeter of the drill pad between the rig and 

sensitive receptors. 





i. Minimize any banging of pipe on the catwalk by careful use of the forklift. 

j. Disable all audible mobile equipment and truck backup alarms. 

7. Air monitoring equipment will be installed at the well locations for all drilling and 

redrilling operations to monitor for total hydrocarbons and hydrogen sulfide. 

Approved 





x. A Topographic Vertical Profile Showing Proposed Location of 

New Wells that Reflects Local Terrain Conditions and that 

Addresses the Potential Visibility of Existing and Proposed 

Well and Other Production Facilities from Residential and 

Recreation Areas 

The topographic vertical profile for the 2009 Plan is intended to provide a visual 

representation of the potential visibility impact of a surface well pumping unit within 

the Inglewood Oil Field, as observed from the surrounding residential and 

recreational areas (receptors) at a viewing height of five feet. The topographic 

vertical profiles included in the Plan assumes: no physical barriers (e.g. structures, 

vegetation); a “worse case”, 40 ft. pumping unit height for each of the respective 

pumping unit locations (including 19 producers of the 24 wells and also including 10 

producers of the 16 alternate wells). The profiles are shown on Attachments 2 

through 30. No other facilities are required in support of the proposed producers and 

injectors after completion that would prompt a visual impact. 

The white to grey shading labeled on each of the profiles as “Surface Model 

Elevation” represents the altitude above sea level (topography) of the region. Blue 

shading indicates potential visibility of the respective pumping unit noted on the 

profile. Pink over blue shading indicates areas where the view of the pumping unit is 

most likely obstructed by buildings and structures. A circle with a radius of one mile 

surrounding each well pumping unit facility provides a representation of distance as 

discussed later in this section. 

The analyses are done at 40 feet above ground level at the locations of the identified 

production well sites, representing the maximum possible height of the pumping unit 

during operation and assuming the largest conventional well pump that could be 

located at the respective site. The data used for the profile is precise to within five 

feet. 

Existing baseline conditions and distance to new facilities are considered in the 

evaluation of visual impacts to receptor sites. The Inglewood Oil Field represents the 

baseline visual condition and the proposed new pumping units represent the new 

facilities potentially impacting visibility. A circle of 1 mile radius has been placed on 

each of the profiles (Attachments 2 through 30) to illustrate any receptor areas up to 

1 mile from the respective new pumping unit. As the distance from the facility 

increases, though the visibility of the facility remains possible, the visual impact will 

become negligible at the 1 mile distance. 

Approved 

The remaining 5 of 24 Plan wells and 6 of 16 alternate wells are proposed as injector 

wells. Said injectors project a minimal visual impact (respective equipment and 

fencing is less than five feet in height) and have therefore not been modeled. 

The following is a list of residential and recreational receptor areas surrounding the 

oil field included in the topographic vertical profile analysis. 

• West Los Angeles College 

• Culver City Park 

• Baldwin Hills Scenic Overlook 

• Kenneth Hahn State Recreation Area 

• Fairfax Ballparks 

• Holy Cross Cemetery 





• Blair Hills 

• Baldwin Hills 

• Windsor Hills 

• Ladera Heights 

• Fox Hills 

• Culver Crest 

In PXP’s attempt to further provide potential visual impact representation of the 

proposed new pumping units for the 2009 Plan wells, we have included examples of 

the same by utilizing baseline oil field photographs taken from receptor locations 

identified during the CEQA analysis that led to the preparation of the CSD 

(Attachments 31 through 36). The baseline photographs reflect all existing 

production facilities prior to drilling of the 2009 Plan wells. The selected examples of 

the potential receptor areas are shown below. The photo ID’s following each of the 

locations listed correspond to the selected photographs contained in the CEQA 

analysis document. 

• Kenneth Hahn State Recreation area (2A) 

• Culver City Park (3C) 

• Ladera Heights (6C) 

• Windsor Hills (7B) 

• West LA College (8A & 8B) 

Visual representations of respective new producing pumping facilities (to scale) were 

superimposed on the photographs as applicable. As with the topographic vertical 

profiles discussed above, we assumed a maximum height of 40’ for each of the 

pumping facilities. Attachments 31 through 36 therefore illustrate the estimated 

visual impacts of new well facilities (if applicable) resulting from the 19 of 24 

producers proposed for the 2009 Drilling Plan year, including the 10 of 16 alternate 

producers. If a receptor location (utilized for Attachments 31 through 36) lies within 

the 1 mile radius shown on any of the topographic visual profiles (Attachments 2 

through 30) the location ID is so noted on the profile. 

Approved 


Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

Approved

2009 Drilling, Redrilling, Well Abandonment, and Well Pad ...

Create successful ePaper yourself

Delete template?

Save as template?