#	Project Name	Permeability (mD)	Salinity (ppm)	Temp (°C)	Polymer Type	Pilot/Full Field	Incremental Recovery (%)	Polymer Retention (µg/g)
1	Aishwariya Lower Fatehgarh	1000–5000	NR; relatively hard/divalent brine	Up to 77 at OWC	HPAM; ~25% initial hydrolysis	Injectivity test → six-well extension → full field
2	Alaska North Slope (Milne Point)	500–5000	2600 (source water)	Very low (Arctic conditions)	HPAM	Pilot (two injector–producer patterns, horizontal wells)
3	Baytex 14-50-25W3	1000	70,000 ppm TDS (3500 ppm hardness)	25	HPAM (Partially Hydrolyzed Polyacrylamide, MW > 20 MDa)	Secondary/Tertiary-Full Field (after waterflood)	~4% incremental OOIP (EUR increase from ~13% waterflood to ~17%)	—
4	Bhagyam	Multi-Darcy; exact value NR			NR in retrieved abstract	Pilot → full field
5	Bohai Bay Block-X/SZ36-1	~2000 average	Field value not reported; Bohai laboratory injection water 9047 TDS	Field value not reported; representative Bohai tests at 65	Hydrophobically associating polyacrylamide, AP-P4	Single-well pilot → well-group trial → large-scale application	>7.1% OOIP as of June 2019	Not reported
6	Canto de Amarao	38–200	0.5	50	—	Tertiary	26
7	Captain EOR	3000–11,000		31	Polymer; exact commercial grade NR in retrieved source	Pilot → Stage 1 → full-field Stage 2	NR; >15 MMbbl enhanced oil produced reported, not %OOIP
8	Chengdao 22F				Powder-form polymer, 3000 ppm	Large-scale offshore, 43 injection wells	11.6 forecast, not observed
9	Chichimene Fm1	100–10,000		“High temperature”; numeric NR		Five-pattern pilot	4–9% by pattern
10	Courtenay/Châteaurenard		Fresh formation/injection water; numeric TDS not reported	30	Emulsion-form partially hydrolyzed polyacrylamide; 900–1000 ppm	Pilot → commercial field expansion	6.6% of pore volume, published basis; not stated as %OOIP	~35
11	Daqing (CNPC)	400–1000	3–7	41	HPAM (150–300 cP solutions)	Full Field	12–25
12	Diadema (CAPSA)	10–5000	15,000	50	Flopaam 3630S (HPAM), 1500–3000 ppm	Tertiary	6–8% OIP	—
13	Diadema Pilot	High perm ~500 mD avg	15,000 ppm NaCl	50 °C	Flopaam 3630S (HPAM), 1500–3000 ppm	Pilot	6–8% OIP	N/A
14	East Bodo	NR in retrieved sources	Water chemistry variable; exact TDS NR		Associative polymer	Three-injector/six-producer pilot	20% OOIP laboratory forecast after waterflood; field % NR
15	East-Messoyakhskoye	50–5000		16	HPAM polymer (≈1830 ppm; 30 cP at surface, 60–80 cP in reservoir)	Pilot	not clear
16	El Corcobo Norte	500–4000	40,000	38	HPAM	Polymer injection pilot	-
17	EPIC001 Offshore Heavy oil	N/A	Field-scale modeling values	N/A	HPAM (modeled), viscosity-optimized	Simulation study (pilot-scale)	Improved vs. waterflood (non-numerical)	Strong dependency on adsorption level
18	Greater Burgan Wara East	300–1000	100,000–270,000	50–70	ATBS-HPAM	Pilot	5–7% OOIP	10–30
19	Greater Burgan Wara PF North	300–800	120,000–240,000	50–70	ATBS-HPAM	Pilot	4.5–6% OOIP	20–65
20	Greater Burgan Wara West	250–900	100,000–240,000	50–80	ATBS-HPAM	Pilot	5–7% OOIP	15–40
21	HTHS Carbonate-Injectivity Test 1	Upper: 10–100+; Lower: 1–20	260,000	120	SAV10 (ATBS-rich sulfonated polymer)	Pilot (single-well injectivity test)		~50 (used in calibrated model)
22	HTHS Carbonate-Injectivity Test 2	Upper: 10–100; Lower: 1–20	264,000	124	SAV10 (ATBS-based, thermally stable polymer)	Pilot (single-well injectivity test)		~50 (model-selected mid-case)
23	JZ9-3 Polymer/SP Flood				Polyacrylamide; 0.12–0.15% 3640C in SP sequence	Three-year polymer flood followed by full-field SP	4% incremental oil from polymer phase
24	Kalamkas Full-Field	>500 mD	~98,700–136,200 ppm TDS	40	HPAM (partially hydrolyzed polyacrylamide): Flopaam 5205 (5% ATBS) and Flopaam 1630S	Full-field expansion	~7.5% (field-wide average over waterflood)	retention ~20% lower vs. standard HPAM in lab/core tests
25	Mangala Field	200–4000	<8000 ppm	65–70	HPAM (+ ASP variant in later stages)	Polymer pilot → full-field	~7% improvement in RF	—
26	Marmul	N/A	High salinity (>150,000 ppm typical of Oman)	>100 °C (HT)	ATBS/HPAM (e.g., SAV10, 15 cP solutions)	Full Field	Improved recovery (exact % not given but significant incremental RF)	N/A
27	Matzen Field 8TH	500–1000	21,000	49	HPAM, 500–1000 ppm (20 MDa, 30% hydrolysis)	Pilot	Good incremental observed, 5–8%	not observed
28	Mauddud DRCC	50–300	150,000–270,000	70–90	Hybrid system (Zr/La crosslinker + Sulfonated HPAM)	Pilot	Not yet quantified	10–30
29	Medicine Hat Glauconitic C (MHGC)	580–1000+ mD	30,000 ppm	21 °C–35 °C	HPAM (Polyacrylamide), specifically FLOPAAM 3330	Pilot (5 horizontal injectors)	6% realized initially; targeted 10% with expansion	Inferred high due to low temperature and clay content (~10%)
30	Minagish Oolite	~50–300	150,000–240,000	70–83	ATBS-HPAM	Pilot	4.5–7.3% OOIP	10–40
31	Minagish Wara	200–800	110,000–210,000	45–65	ATBS-HPAM	Pilot (LTPIT)	Not reported (injectivity focus)	20–50
32	Murphy Seal	500–2000	Generally low to moderate TDS (Seal water is relatively fresh)	18–25	HPAM (Partially Hydrolyzed Polyacrylamide)	Initially a Pilot; expanded to wider field applications	Target ~10–15% over primary production/waterflood	Moderate; influenced by high clay content in some sand facies
33	NIM-R Polymer Injectivity Trial	200–2000 (avg. ≈ 800)	~6000 (reservoir brine)		HPAM polymers of low and high MW (including high-MW Flopaam 3630S)	Pilot (Long-term injectivity trial)	Not reported (injectivity focus)
34	Nimr-E Multiwell Trial	NR in accessible text				Multiwell pilot: 3 horizontal injectors, 4 horizontal producers	~7% IOIP observed/assessed
35	Dalia & Camelia (Angola)	1000	30,000	46	High-MW HPAM (hydrolyzed polyacrylamide)	Pilot	7
36	Offshore Abu Dhabi Carbonate	5	230,000	Not explicitly stated	Thermally and calcium-tolerant polymers (two proprietary polymers, molecular weight optimized by controlled shearing) used with proprietary surfactant system	Pilot (single-well SP CEOR with SWTT)	Not reported as field RF; oil desaturation ΔSo ≈ 33–36% locally
37	Palogrande-Cebu	6–150	—	62	HPAM polymers (FP3230, FP3330, FP5115; low–medium MW, partly sulfonated)	Pilot (two inverted patterns: PG-34, PG-37)	1.86% achieved (PG-34); projected up to ~8.8% (PG-34) and ~2.4% (PG-37)	~39
38	Patos-Marinza & Driza (Albania)	100–2500	high salinity	40–42	Flopaam 3630S (HPAM)	Field case	Polymer flooded areas reaching an ultimate recovery factor (URF) of 30%	—
39	Pelican Lake	3000+	1–30 g/L salinity	16	HPAM	Massive field PF	Recovery 7–10% OOIP (field), 26% (pilot), ultimate 20–38% OOIP	—
40	RAUB UB2 LTPIT	100–500	110,000–200,000	50–70	ATBS-HPAM (lower MW)	Pilot (LTPIT)	Not reported (injectivity focus)	~15–40
41	Raudhatain Upper	100–600	120,000–230,000	55–70	ATBS-HPAM (reduced MW)	Pilot (LTPIT)	Not reported (injectivity focus)	~15–40
42	Rayoso-Grimbek	200–1800	35,000	42	Flopaam 3630S (HPAM), 1500–3000 ppm	Pilots (modular/staged)	14%	17–35 µg/g
43	Sabriyah Upper B.	~30–400	120,000–200,000	~60–75	ATBS-HPAM (≈20–40% ATBS)	Pilot (LTPIT)	Not reported (injectivity focus)	~10–30
44	Sabryah Mauddud	~100–1000	89,000–241,000	~45–70	ATBS-HPAM (15–50% ATBS)	Pilot (LTPIT)	Not reported (injectivity focus)	10–65
45	Shuanghe Elevated-Temperature Pilot	420 average		75	Modified high-MW HPAM S525 and S625	Pilot	3.8 observed by December 1995; 9.8 forecast ultimate
46	Sirikit Oil Field	35		85–95	HPAM polymer	Pilot	-
47	South Turgay Pilot	~400 mD average (range 85–90, 2–2200 mD)	~79,000 ppm	85–90	HPAM terpolymer (acrylamide–acrylic acid–ATBS), SNF Flopaam	Pilot	Not reported (oil rate increased; water cut stabilized)	Not reported
48	SZ36-1 Pilot	NR field	High-salinity/high-hardness brine; exact TDS NR	NR	Hydrophobically associating polymer; AP-P4 identified in later work	Single-well pilot → broader application	Field % NR; laboratory associative-polymer displacement improvement 9.28%
49	Tambaredjo-Sarah Maria	4000–12,000 field T1; laboratory packs 401–877	500 injection; ~4700 formation	38	Flopaam 3630S HPAM; 1000 → 1350 → 2300 ppm	Three-injector pilot; later expansion		Field typically 50–250; full calculated range 14–517; laboratory ~0 ± 20
50	Umm Niqqa Lower Fars-High-Salinity 1-Spot Pilot	1000–2000	166,000 ppm TDS	< 40 °C (≈ 35 °C reservoir)	ATBS-based HPAM	Pilot (one-spot SWCT-based)	≈ 54% additional displacement efficiency vs. produced waterflood	—
51	Uzen	1.3–120 mD	Cretaceous brine (preferred), lower salinity	62 °C	Flopaam 5205 VHM (5% ATBS), 1600 mg/L	Pilot → Field	Economic modeling: positive PI = 1.93 (incremental RF not numerically specified)	Lowest dynamic retention screened polymers
52	XJ6	Avg. 649 mD (up to ~1016 mD in S72–S73)	4212	21	Particle-type polymer system: SMG (Soft Microgel) with SLG + crosslinked polymer gel (LPG)	Pilot	—	—
53	Yariguí–Cantagallo TAP	Injector–producer ranges from ~400 mD up to 3000 mD (3 D)	Injection/formation water chloride ~17,500–18,800 ppm	35–65	Thermally Active Polymer (TAP): expandable sub-micron polymer particles (BWTR29404A, BWTR29398A) with surfactant dispersant	Pilot (two campaigns)	Not reported (%)-incremental oil reported as volumes (64,749 bbl total by December-2023)	NR
54	Zuata-Petrocedeño Pilot	15,000	10,200	46	HPAM (Flopaam 3630S)	Pilot	—